Статті в журналах з теми "Gas production rate"
Щоб переглянути інші типи публікацій з цієї теми, перейдіть за посиланням: Gas production rate.
Оформте джерело за APA, MLA, Chicago, Harvard та іншими стилями
Ознайомтеся з топ-50 статей у журналах для дослідження на тему "Gas production rate".
Біля кожної праці в переліку літератури доступна кнопка «Додати до бібліографії». Скористайтеся нею – і ми автоматично оформимо бібліографічне посилання на обрану працю в потрібному вам стилі цитування: APA, MLA, «Гарвард», «Чикаго», «Ванкувер» тощо.
Також ви можете завантажити повний текст наукової публікації у форматі «.pdf» та прочитати онлайн анотацію до роботи, якщо відповідні параметри наявні в метаданих.
Переглядайте статті в журналах для різних дисциплін та оформлюйте правильно вашу бібліографію.
1
Amaechi, Ugwumba Chrisangelo, Princewill Maduabuchi Ikpeka, Ma Xianlin, and Johnson Obunwa Ugwu. "APPLICATION OF MACHINE LEARNING MODELS IN PREDICTING INITIAL GAS PRODUCTION RATE FROM TIGHT GAS RESERVOIRS." Rudarsko-geološko-naftni zbornik 34, no. 3 (2019): 29–40. http://dx.doi.org/10.17794/rgn.2019.3.4.
Повний текст джерела
2
Liu, Xin, Xilin Shi, Yinping Li, Peng Li, Kai Zhao, Hongling Ma, and Chunhe Yang. "Maximum gas production rate for salt cavern gas storages." Energy 234 (November 2021): 121211. http://dx.doi.org/10.1016/j.energy.2021.121211.
Повний текст джерела
3
GÜmrah, B. GÜyagÜler, F. "Gas Production Rate Optimization by Genetic Algorithm." Energy Sources 23, no. 3 (April 2001): 295–304. http://dx.doi.org/10.1080/00908310151134040.
Повний текст джерела
4
Zhong, Haiquan, Chengjie Zhao, Zhiyu Xu, and Chuangen Zheng. "Economical Optimum Gas Allocation Model Considering Different Types of Gas-Lift Performance Curves." Energies 15, no. 19 (September 22, 2022): 6950. http://dx.doi.org/10.3390/en15196950.
Повний текст джерелаАнотація:
The traditional optimum modes of gas-lift production are usually established by taking the injected gas rate as a decision variable and maximum oil production as the objective function. After solving the model, the injected gas rates of single wells are obtained, and then the oil productions of single wells, the total oil productions of well groups and economic profit can be obtained. However, the models do not take both different types of gas-lift performance curves (GLPCs) and the cost factors of gas-lift production technique into account. On the basis of GLPCs, this paper introduces the factors of a gas-lift production technique, which includes the water cut of crude oil, cost of gas injection and water treatment, and oil and gas prices. The concept of a gas-lift economic performance curve (GLEPC) is proposed, and an optimum gas allocation model is established, considering different types of GLPCs and taking economic benefits as the objective, and the model is solved by the method of mixed penalty function. Taking gas-lift well group JD as an example, four gas-lift gas allocation schemes are obtained, and the proposed economical optimum model is applied to optimize gas allocation and analyze profit. What is more, the oil production rate and the result of optimum gas allocation taking maximum oil production rate as the objective in the model are calculated and compared. Then the gas allocation scheme with maximum economical profit is selected, and the significance of considering different types of GLPCs and taking economic benefits as the objective to gas allocation is confirmed.
5
Bagherpour, Morteza, MH Bagherpour, and K. Roodani. "Forecasting Gas Production Rate in Underground Gas Reservoirs Using Artificial Neural Networks." Universal Journal of Engineering Science 2, no. 4 (May 2014): 73–76. http://dx.doi.org/10.13189/ujes.2014.020402.
Повний текст джерела
6
Wei, C., S. X. Lin, J. L. Wu, G. Y. Zhao, T. T. Zhang, and W. S. Zheng. "Effects of supplementing vitamin E on in vitro rumen gas production, volatile fatty acid production, dry matter disappearance rate, and utilizable crude protein." Czech Journal of Animal Science 60, No. 8 (April 9, 2018): 335–41. http://dx.doi.org/10.17221/8402-cjas.
Повний текст джерелаАнотація:
Two in vitro trials were carried out to study the effects of supplementing vitamin E (V<sub>E</sub>) on rumen fermentation. In Trial I, four levels of V<sub>E</sub> product (purity 50%), i.e. 0, 15, 30, and 60 mg/kg dry matter (DM) of feed (equivalent to 0, 7.5, 15, 30 IU V<sub>E</sub>/kg DM) were supplemented to a typical feed mixture, respectively, as experimental treatments. The gas test technique of Menke et al. (1979) was used to measure gas and volatile fatty acid (VFA) production. In Trial II, the in vitro incubation technique of Zhao and Lebzien (2000) was used to determine DM disappearance rate and utilizable crude protein (uCP). Four levels of V<sub>E</sub>, i.e. 0, 7.5, 15, 30 IU/kg DM were supplemented to the same feed mixture as in Trial I, respectively, as experimental treatments. The results showed that supplementing V<sub>E</sub> increased total gas production (P < 0.01) and tended to increase methane (CH<sub>4</sub>) production (P = 0.087). Supplementing V<sub>E</sub> also increased total VFA (P < 0.05) and propionate (P < 0.05), tended to increase acetate production (P = 0.084), and significantly increased DM disappearance rate (P < 0.05) and uCP (P < 0.01). It was concluded that supplementing V<sub>E</sub> at 30 IU/kg DM under the conditions of present trials with 11.1 IU/kg DM in the feed mixture improved in vitro rumen fermentation of feed mixture. Further research is necessary to confirm the effects of supplementing V<sub>E</sub> using in vivo trials.
7
Anozie, A. N., and Y. B. Adeboye. "Correlations for Gas Production Rate in Batch Anaerobic Digesters." Energy Sources, Part A: Recovery, Utilization, and Environmental Effects 31, no. 13 (August 14, 2009): 1131–40. http://dx.doi.org/10.1080/15567030802459313.
Повний текст джерела
8
Lin, Chien C. "The Radiolytic Gas Production Rate in Boiling Water Reactors." Nuclear Science and Engineering 99, no. 4 (August 1988): 390–93. http://dx.doi.org/10.13182/nse88-a23567.
Повний текст джерела
9
Balcerak, Ernie. "High rate of methane leakage from natural gas production." Eos, Transactions American Geophysical Union 94, no. 42 (October 15, 2013): 384. http://dx.doi.org/10.1002/2013eo420008.
Повний текст джерела
10
Cao, Cheng, Jianxing Liao, Zhengmeng Hou, Hongcheng Xu, Faisal Mehmood, and Xuning Wu. "Utilization of CO2 as Cushion Gas for Depleted Gas Reservoir Transformed Gas Storage Reservoir." Energies 13, no. 3 (January 25, 2020): 576. http://dx.doi.org/10.3390/en13030576.
Повний текст джерелаАнотація:
Underground gas storage reservoirs (UGSRs) are used to keep the natural gas supply smooth. Native natural gas is commonly used as cushion gas to maintain the reservoir pressure and cannot be extracted in the depleted gas reservoir transformed UGSR, which leads to wasting huge amounts of this natural energy resource. CO2 is an alternative gas to avoid this particular issue. However, the mixing of CO2 and CH4 in the UGSR challenges the application of CO2 as cushion gas. In this work, the Donghae gas reservoir is used to investigate the suitability of using CO2 as cushion gas in depleted gas reservoir transformed UGSR. The impact of the geological and engineering parameters, including the CO2 fraction for cushion gas, reservoir temperature, reservoir permeability, residual water and production rate, on the reservoir pressure, gas mixing behavior, and CO2 production are analyzed detailly based on the 15 years cyclic gas injection and production. The results showed that the maximum accepted CO2 concentration for cushion gas is 9% under the condition of production and injection for 120 d and 180 d in a production cycle at a rate of 4.05 kg/s and 2.7 kg/s, respectively. The typical curve of the mixing zone thickness can be divided into four stages, which include the increasing stage, the smooth stage, the suddenly increasing stage, and the periodic change stage. In the periodic change stage, the mixed zone increases with the increasing of CO2 fraction, temperature, production rate, and the decreasing of permeability and water saturation. The CO2 fraction in cushion gas, reservoir permeability, and production rate have a significant effect on the breakthrough of CO2 in the production well, while the effect of water saturation and temperature is limited.
11
Hamaguchi, Ryokichi, Yuki Nishimura, Gen Inoue, Yosuke Matsukuma, and Masaki Minemoto. "Gas Hydrate Decomposition Rate in Flowing Water." Journal of Energy Resources Technology 129, no. 2 (August 19, 2006): 102–6. http://dx.doi.org/10.1115/1.2718579.
Повний текст джерелаАнотація:
The development of methane hydrate (MH), which exists under the ocean floor, has recently been brought to public attention. However, the production technology has not yet been established. It is important to understand the decomposition phenomenon of MH for an investigation of the safety and the profitability of production systems. In this research, the gas hydrate decomposition rate in flowing water was measured using HCFC141b hydrate as a substitute for MH. When the water temperature was higher than the boiling point of the decomposition gas, it was observed that the decomposition gas increased the decomposition rate. Moreover, the decomposition phenomenon was simulated by the lattice gas automaton method in order to establish the technique which analytically estimates the decomposition rate. The validity of the simulation method was shown by comparing the experiments. Furthermore, the formula between Reynolds number and Nusselt number was obtained, which express the heat transfer around the gas hydrate lump.
12
Elaiyaraju, P., and N. Partha. "Studies on biogas production by anaerobic process using agroindustrial wastes." Research in Agricultural Engineering 62, No. 2 (June 30, 2016): 73–82. http://dx.doi.org/10.17221/65/2013-rae.
Повний текст джерелаАнотація:
This study investigated the effect of factors namely temperature, pH, substrate concentration on sago and tannery effluents by the anaerobic digestion process for biogas production. Response surface methodology with the Central Composite Design (CCD) experiments verified that the biogas production rates were mainly affected by operating temperature, pH, and substrate concentration. The experiments were carried out by two distinct effluents at different organic loading rate under mesophilic range of temperature 31–33°C. Co-digestion was carried out for a period of 21 days. The gas produced was measured by the liquid displacement system. Meanwhile, the highest biogas yields – 80% of CH<sub>4</sub> and 20% of CO<sub>2</sub> –produced in the combined effluent were confirmed by the Gas Chromatography (GC) analysis.
13
Saepudin, Deni, Edy Soewono, Kuntjoro Adji Sidarto, Agus Yodi Gunawan, Septoratno Siregar, and Pudjo Sukarno. "An Investigation on Gas Lift Performance Curve in an Oil-Producing Well." International Journal of Mathematics and Mathematical Sciences 2007 (2007): 1–15. http://dx.doi.org/10.1155/2007/81519.
Повний текст джерелаАнотація:
The main objective in oil production system using gas lift technique is to obtain the optimum gas injection rate which yields the maximum oil production rate. Relationship between gas injection rate and oil production rate is described by a continuous gas lift performance curve (GLPC). Obtaining the optimum gas injection rate is important because excessive gas injection will reduce production rate, and also increase the operation cost. In this paper, we discuss a mathematical model for gas lift technique and the characteristics of the GLPC for a production well, for which one phase (liquid) is flowing in the reservoir, and two phases (liquid and gas) in the tubing. It is shown that in certain physical condition the GLPC exists and is unique. Numerical computations indicate unimodal properties of the GLPC. It is also constructed here a numerical scheme based on genetic algorithm to compute the optimum oil production.
14
Sindland, Caroline, and Merete Tangstad. "Production Rate of SiO Gas from Industrial Quartz and Silicon." Metallurgical and Materials Transactions B 52, no. 3 (April 21, 2021): 1755–71. http://dx.doi.org/10.1007/s11663-021-02143-4.
Повний текст джерелаАнотація:
AbstractThe production rate of SiO gas from industrial quartz and silicon has been investigated by isothermal heat treatment experiments. Mixtures of silicon and different quartz samples have been heated to temperatures ranging from 1650 °C to 1950 °C and held for 30 to 120 minutes before cooling. The weight loss of each sample has been correlated to degree of reaction and a model for the reaction rate of Si + SiO2 has been developed based on these values. Five different types of industrial quartz were used in the experiments. No significant difference was found in their reaction rate, even though there are large variations in impurity content, melting rate, decrepitation, and phase transformation rate of each sample. Further on, it is shown that the reaction rate of silicon mixed with various types of quartz can be described by an Arrhenius equation: $${{\rm {d}}\alpha /{\rm {d}}t = k_0 \, A \, {\rm {exp}} (- Q / RT)}$$ d α / d t = k 0 A exp ( - Q / R T ) . A reaction constant (k0) equal to $${6.25 \, 10^8 {\rm {g}}\, {\rm {s}}^{-1}\, {\rm{m^{-2}}}}$$ 6.25 10 8 g s - 1 m - 2 and an activation energy (Q) equal to $${557\, {\rm {kJ \, mol^{-1}}}}$$ 557 kJ mol - 1 were obtained by linear regression. The degree of reaction ($${\alpha }$$ α ) is shown to be increasing with available reaction area, temperature, and time.
15
Volkov, A. N., and G. A. Lukyanov. "Thermal state and gas production rate of rotating cometary nuclei." Solar System Research 42, no. 3 (June 2008): 209–25. http://dx.doi.org/10.1134/s0038094608030039.
Повний текст джерела
16
Wheler, G. H. Trevor, David Brandon, Aaron Clemons, Crystal Riley, John Kendall, D. Lynn Loriaux, and J. David Kinzie. "Cortisol Production Rate in Posttraumatic Stress Disorder." Journal of Clinical Endocrinology & Metabolism 91, no. 9 (September 1, 2006): 3486–89. http://dx.doi.org/10.1210/jc.2006-0061.
Повний текст джерелаАнотація:
Abstract Context: Several authors have reported the unsuspected finding of low cortisol levels (urinary, salivary, and serum) in patients with posttraumatic stress disorder (PTSD). Objective: Our objective was to assess concentrations of cortisol and its predominant metabolites, cortisol production rate (CPR), and glucocorticoid receptor (GR) binding characteristics in PTSD compared with normal subjects. Design: Matched PTSD patients and control subjects had CPR determined by a stable isotope dilution technique after infusion of deuterated cortisol. Serum cortisol, urinary cortisol, and its metabolites were measured by gas chromatography/mass spectrometry. GR binding capacity (Ro) and ligand binding affinity (Kd) were measured in mononuclear leukocytes. Setting: All subjects were tested during a 40-h admission in an inpatient clinical research center. Patients and Participants: Ten patients with PTSD were matched by age and gender with 10 controls. Outcome Measures: Statistical comparison was conducted for various measures of cortisol in PTSD patients and normal subjects. Results: No statistical difference was found in mean level or circadian pattern of cortisol secretion using serum or salivary immunoassay detection methods. Although in the normal range, urinary cortisol by immunoassay showed statistically lower values over a 24-h period in PTSD patients compared with controls. This finding was not confirmed by gas chromatography/mass spectrometry determination of cortisol or its metabolites. CPR was not statistically different between these groups. GR also showed no alteration in Ro or Kd between the groups. Conclusion: The data indicate that PTSD in the chronic and unprovoked state is not characterized by an acute biological stress response.
17
Okorocha, Ikenna Tobechukwu, Chuka Emmanuel Chinwuko, Chika Edith Mgbemena, and Chinedum Ogonna Mgbemena. "Gas lift optimization in the oil and gas production process: a review of production challenges and optimization strategies." International Journal of Industrial Optimization 1, no. 2 (August 21, 2020): 61. http://dx.doi.org/10.12928/ijio.v1i2.2470.
Повний текст джерелаАнотація:
Gas Lift operation involves the injection of compressed gas into a low producing or non-performing well to maximize oil production. The oil produced from a gas lift well is a function of the gas injection rate. The optimal gas injection rate is achieved by optimization. However, the gas lift, which is an artificial lift process, has some drawbacks such as the deterioration of the oil well, incorrect production metering, instability of the gas compressor, and over injection of gas. This paper discusses the various optimization techniques for the gas lift in the Oil and Gas production process. A systematic literature search was conducted on four databases, namely Google Scholar, Scopus, IEE Explore and DOAJ, to identify papers that focused on Gas lift optimizations. The materials for this review were collected primarily via database searches. The major challenges associated with gas lift were identified, and the different optimization strategies available in the literature reviewed. The strategies reviewed were found to be based on artificial intelligence (AI) and machine learning (ML). The implementation of any of the optimization strategies for the gas lift will enhance profitability, reduce operational cost, and extend the life of the wells.
18
Salaudeen, Ibraheem, Daniyar Bopbekov, and Abdulsalam Abdulkarim. "Optimization of petroleum production system using Nodal Analysis Program." Nigerian Journal of Technological Development 19, no. 1 (June 5, 2022): 1–8. http://dx.doi.org/10.4314/njtd.v19i1.1.
Повний текст джерелаАнотація:
This research attempted to optimize petroleum production system of well X in Field Y in Niger Delta region of Nigeria located in Gulf of Guinea by adopting Nodal analysis technique. A non-commercial software known as Nodal Analysis Program was used for the analysis. The dataset available from offset well were used as the input parameters to the software for the selection of the most economical production string for the new well. The production system has two adjustable components: vertical tubing and nearly horizontal flowline. The flowline inclination is -3.0 degree to the horizontal. The productivity index of the well was obtained in order to know the deliverability of the well. Several combinations of the tubing and flowline have been used in the analysis of the production system. The optimal configuration of the production system components is selected by the maximum operating flow rate of 1118 stb/day. The stable operational region is determined with the assumption that the system will be stable above the flow rate corresponding to the minimum on the outflow performance relation (OPR) curve. The introduction of the gas lift into the optimal system configuration increased the operating oil rate from 1118 stb/day to production rate of approximately 1287 stb/day, but the operating oil rate decreased with higher gas injection rate to 1115 stb/day. The optimal gas injection rate is selected by highest operating oil rate. The fluctuations in the oil price did not change the selection of the optimal configuration and gas injection rate. The investigation of the flow regime in the system before and after gas lift has revealed that the effect of gas injection on the flow regime is minor, probably due to low injection rate. Disperse flow was the flow regimes investigated and established for vertical flow (tubing) before and after gas injection. While on the other hand, elongated bubble was established to be the flow regime in flowline before gas injection and slug flow after gas injection in the flowline.
19
Eckmann, David M., and Scott L. Diamond. "Surfactants Attenuate Gas Embolism-induced Thrombin Production." Anesthesiology 100, no. 1 (January 1, 2004): 77–84. http://dx.doi.org/10.1097/00000542-200401000-00015.
Повний текст джерелаАнотація:
Background There are no pharmacologic strategies to prevent embolism bubble-induced blood clot formation. The authors conducted experiments to measure thrombin production in sheared whole blood in the presence and absence of bubbles and three surface-active compounds. Methods Blood samples were obtained from six volunteers seven times. The thrombin-specific substrate Boc-VPR-MCA was added to citrated blood diluted with HEPES-buffered saline. Experimental groups were as follows: sparging (air microbubble embolization) with surfactant present; sparging alone; surfactant alone; and neither surfactant nor sparging. The surfactants were Dow Corning Antifoam 1510US, Perftoran, and Pluronic F-127. Blood was sheared by a cone-plate viscometer at 100 and 500 s-1 for 5, 10, and 20 min at 37 degrees C, pipetted into excess stop buffer, and evaluated fluorimetrically. Mean values of fluorescence intensity +/- SDs for each group were compared using ANOVA. Differences were considered significant at P < 0.05 using the Bonferroni correction. Results For fixed shear rate, thrombin production increased 2.3- to 5.7-fold (P < 0.05) as shear duration lengthened. For fixed shear duration, thrombin production increased 1.9- to 3.9-fold (P < 0.05) with increasing shear rate. For fixed shear rate and duration, sparging increased thrombin production 2.1- to 3.7-fold (P < 0.05). Surfactant addition without sparging did not change thrombin production (P > 0.05). Surfactants attenuated thrombin production in sparged samples 31.8-70.9% (P < 0.05). Conclusions Thrombin production is shear rate and duration-dependent. Sparging increases thrombin production. Surfactants added before sparging attenuate thrombin production. Surfactants may have a clinical application to attenuate gas embolism-induced clotting.
20
Nguyen, Thanh Phu, Van Hoanh Nguyen, Quoc Dung Ta, and The Ha Le. "Assessing the effect of gas temperature on gas well performance." Petrovietnam Journal 6 (July 22, 2022): 49–58. http://dx.doi.org/10.47800/pvj.2022.06-06.
Повний текст джерелаАнотація:
Gas temperature is an essential parameter in estimating production rate and pressure model inside the production tubing. Three heat transfer mechanisms named as conduction, convection and radiation have been applied to identify the gas temperature declination. Gas wells with bottom hole temperature greater than 160oC and gas rates reaching 55 million standard ft3 per day (MMscf/d) indicate a higher heat loss due to convection than the other two mechanisms. Conduction is the main factor in explaining heat diffusion to the surrounding at the top of the well. The study presents a strong similarity in value compared to the field data by combining Gray correlation and heat transfer model to predict the bottom hole pressure with an error of approximately 3%. Additionally, the gas temperature affects gas rate prediction through gas viscosity and Z factor. With the gas composition mostly containing C1 (70.5%), gas viscosity and Z coefficient at the wellhead are not as high as 0.017 cp and 0.92 respectively. It is possible to have a two-phase flow, then a temperature model along the production tubing is necessary to ensure the gas production rate.
21
Xiuwu, Wang, Liao Ruiquan, Liu Jie, and Wang Xiaowei. "Visible Research of Loading Speed in Vertical Gas Well." Open Petroleum Engineering Journal 8, no. 1 (May 29, 2015): 163–66. http://dx.doi.org/10.2174/1874834101508010163.
Повний текст джерелаАнотація:
For gas well under certain conditions, formation water production is inevitable in the later development; Formation water production is harmful to the normal production, it may cause liquid loading, flooding or even stop production. Based on the study of liquid loading and the rate laws of liquid loading, taking corresponding measures for the gas well is important. Simulating formation liquid production of gas wells with single rate under wellbore conditions, observing and measuring liquid loading rate through the experiment, summing up the liquid loading rate law of wellbore, are significant to the stability of gas well.
22
Wu, Guo Yun, and Jiao Li. "Rational Production Proration of Gas Wells in Unconsolidated Sandstone Gas Reservoir." Applied Mechanics and Materials 121-126 (October 2011): 1249–53. http://dx.doi.org/10.4028/www.scientific.net/amm.121-126.1249.
Повний текст джерелаАнотація:
Multi-layered unconsolidated sandstone gas reservoir is featured by unconsolidated lithology, interbeded gas-water zones and active edge water. Irrational production proration will lead to water breakthrough and sand inflow(AOF) is already incompetent in solving problems nowadays. Based on multipoint well test deliverability analysis, production data dynamic analysis, single well controlled reserves and critical situation of inflow calculation, and combining the calculation of minimum liquid hold-up gas rate an maximum erosion gas rate, meanwhile considering balanced gas recovery factor, balanced pressure drop, safe sand inflow and safe liquid hold-up, the multi-factor production plan has been set up, which is improved and adjusted by integrating water influx performance and years of stable production, through gas reservoir numerical simulation. A scientific and rational production proration pattern particularly for this type of gas reservoir has been determined. The reservoir simulation results of case study show that the water production in gas well can be controlled and the gas reservoir sustained stable production can last more than 1.3 year.
23
Mustaqim, I. Z., and D. W. Maulana. "The Effect of NaOH and LaCoO3 Perovskite on HHO Gas Production Rate." Journal of Physics: Conference Series 2344, no. 1 (September 1, 2022): 012003. http://dx.doi.org/10.1088/1742-6596/2344/1/012003.
Повний текст джерелаАнотація:
Abstract Utilization of renewable energy such as solar energy, wind energy, require a technology to store energy since production and consumption energy isn’t always at the same time. Hydrogen appears as an alternative solution to store energy since it has high energy density and can be easily obtained from water by electrolysis reaction. Electrolysis produces hydrogen and oxygen gas and when it combines forming HHO gas. There are many factors that can influence HHO gas production, such as electrolyte concentration and utilization of catalyst. In this research, we observed the effect of NaOH electrolyte concentration and catalyst LaCoO3 concentration toward production of HHO gas. Catalyst LaCoO3 is synthesized by sol-gel method with calcination over 900°C, however particle of LaCoO3 that formed still submicron-sized. To obtain catalyst LaCoO3 that disperse in electrolyte suspension, it is treated by beads milling process to minimize the size of particle. Experiment result showed that increasing NaOH electrolyte concentration will affect to increment of HHO gas production. The most optimal HHO gas production from all variation of catalyst LaCoO3 is when using 3 M of NaOH electrolyte concentration. However, addition of catalyst LaCoO3 in suspension electrolyte will drop HHO gas production.
24
Liu, Qi-guo, Wei-hong Wang, Hua Liu, Guangdong Zhang, Long-xin Li, and Yu-long Zhao. "Production Rate Analysis of Fractured Horizontal Well considering Multitransport Mechanisms in Shale Gas Reservoir." Geofluids 2018 (October 18, 2018): 1–17. http://dx.doi.org/10.1155/2018/3148298.
Повний текст джерелаАнотація:
Shale gas reservoir has been aggressively exploited around the world, which has complex pore structure with multiple transport mechanisms according to the reservoir characteristics. In this paper, a new comprehensive mathematical model is established to analyze the production performance of multiple fractured horizontal well (MFHW) in box-shaped shale gas reservoir considering multiscaled flow mechanisms (ad/desorption and Fick diffusion). In the model, the adsorbed gas is assumed not directly diffused into the natural macrofractures but into the macropores of matrix first and then flows into the natural fractures. The ad/desorption phenomenon of shale gas on the matrix particles is described by a combination of the Langmuir’s isothermal adsorption equation, continuity equation, gas state equation, and the motion equation in matrix system. On the basis of the Green’s function theory, the point source solution is derived under the assumption that gas flow from macropores into natural fractures follows transient interporosity and absorbed gas diffused into macropores from nanopores follows unsteady-state diffusion. The production rate expression of a MFHW producing at constant bottomhole pressure is obtained by using Duhamel’s principle. Moreover, the curves of well production rate and cumulative production vs. time are plotted by Stehfest numerical inversion algorithm and also the effects of influential factors on well production performance are analyzed. The results derived in this paper have significance to the guidance of shale gas reservoir development.
25
Song, Gihun, Hyun Suk Lee, and Hyundon Shin. "Three-Dimensional Modelling of Desorbed Gas Volume and Comparison to Gas Production Rate in the Montney Plays, Western Canadian Sedimentary Basin." Geofluids 2021 (March 15, 2021): 1–15. http://dx.doi.org/10.1155/2021/6674183.
Повний текст джерелаАнотація:
Shale reservoir has been focused among unconventional resources since the first extraction of free and adsorbed gas from the low-permeable Barnett Shale via horizontal drilling and hydraulic fracturing. In the beginning of production, free gas was rapidly recovered through an artificial fracture system, and then, desorbed gas followed at the final stage due to a decrease of reservoir pressure. This desorbed gas volume commonly occupies 10 to 40% of total gas production in shale gas play although it shows wide variety in cumulative gas volume and production time. The largest gas production in Canada is recovered from either tight sandstone or shale reservoirs. The Montney play in Western Canadian Sedimentary Basin (WCSB) has produced up to 80% of Canadian natural gas production. The desorbed gas production from this play has been reported up to 10% of total produced gas. The distribution and productivity of the desorbed gas have not been fully studied. Therefore, we focus to understand the distribution of the desorbed gas volume of eastern, middle, and northwestern areas in the Montney play. The desorbed gas volume within these areas was estimated from the relationship among canister, illite, and shale volumes in core samples and well logs. The average shale volume fraction in eastern area is 0.38 v / v , the average illite mineral volume fraction is 0.25 v / v , and the average desorbed gas volume refers to 8.52 scf/ton. In middle area, calculated volume represents 0.34 v / v , 0.216 v / v , and 8.15 scf/ton as listed above. The northwestern area also shows 0.65 v / v , 0.4 v / v , and 9.78 scf/ton, respectively. 3D models of each area indicated relatively rich and lack parts of desorbed gas volume. These estimated desorbed gas volume and gas production history were compared in order to understand when and how the desorbed gas would affect to gas production. It shows strong positive relationship, gradually increasing correlation to the later stage (from 24-44 months to 36-44 months) of gas production in the entire areas. This result implies that the estimation of later stage gas productivity is able from the estimated volume of desorbed gas, and also, the total gas production can be forecast in shale gas reservoir. Northwestern area in Montney play preserves relatively abundant desorbed gas volume, which will be dominant after 24 months of production.
26
Denney, Dennis. "Sand-Production Prediction in High-Rate Perforated and Openhole Gas Wells." Journal of Petroleum Technology 52, no. 03 (March 1, 2000): 49–50. http://dx.doi.org/10.2118/0300-0049-jpt.
Повний текст джерела
27
Markovskii, A. I. "Stationary production rate of a well draining two gas-bearing formations." Fluid Dynamics 42, no. 4 (August 2007): 673–80. http://dx.doi.org/10.1134/s0015462807040175.
Повний текст джерела
28
Chen, Jianxun, Shenglai Yang, Dongfan Yang, Hui Deng, Jiajun Li, Yu Huang, and Cheng Zou. "Influence of Pore Structure and Solid Bitumen on the Development of Deep Carbonate Gas Reservoirs: A Case Study of the Longwangmiao Reservoir in Gaoshiti–Longnusi Area, Sichuan Basin, SW China." Energies 13, no. 15 (July 25, 2020): 3825. http://dx.doi.org/10.3390/en13153825.
Повний текст джерелаАнотація:
A variable sedimentary environment and accumulation process leads to a complex pore structure in deep carbonate gas reservoirs, and the physical properties are quite different between layers. Moreover, some pores and throats are filled with solid bitumen (SB), which not only interferes with reservoir analysis, but also affects efficient development. However, previous studies on SB mainly focused on the accumulation process and reservoir analysis, and there are few reports about the influence on development. In this paper, through scanning electron microscope analysis, SB extraction, gas flow experiments and depletion experiments, and a similar transformation between experimental results and reservoir production, the production characteristics of carbonate gas reservoirs with different pore structures were studied, and the influence of SB on pore structure, reservoir analysis and development were systematically analyzed. The results show that permeability is one of the key factors affecting gas production rate and recovery, and the production is mainly contributed by high-permeability layers. Although the reserves are abundant, the gas production rate and recovery of layers with a low permeability are relatively low. The SB reduces the pore and throat radius, resulting in porosity and permeability being decreased by 4.73–6.28% and 36.02–3.70%, respectively. With the increase in original permeability, the permeability loss rate decreases. During development, the loss rate of gas production rate is much higher than that of permeability. Increasing the production pressure difference is conducive to reducing the influence. SB also reduces the recovery, which leads to the loss rate of gas production being much higher than that of porosity. For reservoirs with a high permeability, the loss rates of gas production rate and the amount produced are close to those of permeability and porosity. Therefore, in the reservoir analysis and development of carbonate gas reservoirs bearing SB, it is necessary and significant to analyze the influence of reservoir types.
29
Helmy, Mia Ferian. "Optimasi Intermittent Gas lift Pada Sumur AB-1 Lapangan Brownfield." Jurnal Mineral, Energi dan Lingkungan 2, no. 1 (August 16, 2018): 32. http://dx.doi.org/10.31315/jmel.v2i1.2182.
Повний текст джерелаАнотація:
Gas lift is one of the artificial lift method that has mechanism to decrease the flowing pressure gradient in the pipe or relieving the fluid column inside the tubing by injecting amount of gas into the annulus between casing and tubing. The volume of injected gas was inversely proportional to decreasing of flowing pressure gradient, the more volume of gas injected the smaller the pressure gradient. Increasing flowrate is expected by decreasing pressure gradient, but it does not always obtained when the well is in optimum condition. The increasing of flow rate will not occured even though the volume of injected gas is abundant. Therefore, the precisely design of gas lift included amount of cycle, gas injection volume and oil recovery estimation is needed. At the begining well AB-1 using artificial lift method that was continuos gas lift with PI value assumption about 0.5 STB/D/psi. Along with decreasing of production flow rate dan availability of the gas injection in brownfield, so this well must be analyze to determined the appropriate production method under current well condition. There are two types of gas lift method, continuous and intermittent gas lift. Each type of gas lift has different optimal condition to increase the production rate. The optimum conditions of continuous gaslift are high productivity 0.5 STB/D/psi and minimum production rate 100 BFPD. Otherwise, the intermittent gas lift has limitations PI and production rate which is lower than continuous gas lift.The results of the analysis are Well AB-1 has production rate gain amount 20.75 BFPD from 23 BFPD became 43.75 BFPD with injected gas volume 200 MSCFPD and total cycle 13 cycle/day. This intermittent gas lift design affected gas injection volume efficiency amount 32%.
30
Jahandideh, Alireza, and Amirhossian Chambaria. "Estimation of Production Function and Labor Productivity Rate in Aghajari Oil and Gas Production Company." Singaporean Journal of Business Economics and Management Studies 5, no. 12 (June 2017): 8–21. http://dx.doi.org/10.12816/0039976.
Повний текст джерела
31
Pallipurath, Mohamed Iqbal. "Effect of Bed Deformation on Natural Gas Production from Hydrates." Journal of Petroleum Engineering 2013 (May 12, 2013): 1–9. http://dx.doi.org/10.1155/2013/942597.
Повний текст джерелаАнотація:
This work is based on modelling studies in an axisymmetric framework. The thermal stimulation of hydrated sediment is taken to occur by a centrally placed heat source. The model includes the hydrate dissociation and its effect on sediment bed deformation and resulting effect on gas production. A finite element package was customized to simulate the gas production from natural gas hydrate by considering the deformation of submarine bed. Three sediment models have been used to simulate gas production. The effect of sediment deformation on gas production by thermal stimulation is studied. Gas production rate is found to increase with an increase in the source temperature. Porosity of the sediment and saturation of the hydrate both have been found to significantly influence the rate of gas production.
32
Nasriani, Khan, Graham, Ndlovu, Nasriani, Mai, and Rafiee. "An Investigation into Sub-Critical Choke Flow Performance in High Rate Gas Condensate Wells." Energies 12, no. 20 (October 20, 2019): 3992. http://dx.doi.org/10.3390/en12203992.
Повний текст джерелаАнотація:
There have been some correlations in the literature to predict the gas and liquid flow rate through wellhead chokes under subcritical flow conditions. The majority of these empirical correlations have been developed based on limited production data sets that were collected from a small number of fields. Therefore, these correlations are valid within the parameter variation ranges of those fields. If such correlations are used elsewhere for the prediction of the subcritical choke flow performance of the other fields, significant errors will occur. Additionally, there are only a few empirical correlations for sub-critical choke flow performance in high rate gas condensate wells. These led the authors to develop a new empirical correlation based on a wider production data set from different gas condensate fields in the world; 234 production data points were collected from a large number of production wells in twenty different gas condensate fields with diverse reservoir conditions and different production histories. A non-linear regression analysis method was applied to their production. The new correlation was validated with a new set of data points from some other production wells to confirm the accuracy of the established correlation. The results show that the new correlation had minimal errors and predicted the gas flow rate more accurately than the other three existing models over a wider range of parameter variation ranges.
33
Liu, Du, Longyong Shu, Yanbin Wang, Zhonggang Huo, Shihu Zhao, and Xing Xiong. "Optimal Injection Parameters for Enhancing Coalbed Methane Recovery: A Simulation Study from the Shizhuang Block, Qinshui Basin, China." Geofluids 2022 (October 11, 2022): 1–13. http://dx.doi.org/10.1155/2022/3311827.
Повний текст джерелаАнотація:
The injection of N2 into coal reservoir has great potential in improving recovery of coalbed methane (CBM). In this study, a numerical model was established based on the GEM component model to evaluate the influences of different N2 injection parameters (production injection well spacing, gas injection timing, gas injection duration, gas injection rate, and the bottom-hole injection pressure) on the production of CBM in the Shizhuang Block of Qinshui Basin, China. Based on the economic benefit of CBM production, the production increasing rate and nitrogen replacement ratio were established to optimize the N2 injection parameters. The results show that (1) the production injection well spacing had the greatest influence on CBM production, followed by injection duration and the bottom-hole injection pressure, and injection timing and injection rate had a relatively small influence. (2) With increasing gas injection duration, injection rate, and the bottom-hole injection pressure, the rate of production increased and the nitrogen replacement ratio decreased. (3) The optimal N2 injection scheme was revealed with the production injection well spacing of 180 m, the injection timing of a second year after gas production, an injection duration of 7 years, an injection rate of 5000 m3/d, and a bottom-hole injection pressure of 10 MPa. Under these conditions, the rate of production increasing rate, the nitrogen displacement ratio, and the regional recovery of the four production wells were 18.14%, 0.5, and 48.96%, respectively, some 8.88% higher than that without nitrogen displacement, showing good effect in terms of CBM production.
34
Song, Liu, Liu Xiaojie, Lyu Qing, Zhang Xusheng, and Qie Yana. "Study on the Appropriate Production Parameters of a Gas-injection Blast Furnace." High Temperature Materials and Processes 39, no. 1 (February 11, 2020): 10–25. http://dx.doi.org/10.1515/htmp-2020-0005.
Повний текст джерелаАнотація:
AbstractThe change regulations of the smelting parameters in a gas-injection blast furnace are investigated using theoretical calculations. The results show that when the volume of gas injected, the oxygen enrichment rate and the theoretical combustion temperature of tuyere are 600 m3/tHM, 10% and 1950~2200∘C, respectively, the conditions meet the smelting requirements of a blast furnace. With the increase of the oxygen enrichment rate, the required air volume decreases, the contents of CO and H2 in the top gas increase, and the content of CO2 first increases and then decreases.With an increase of the volume of gas injected, the coke rate decreases. In addition, when the oxygen enrichment rate and the volume of gas injected are 10% and 600 m3/tHM, respectively, the CO content of the top gas constantly increases with the increase of the coke rate, while the H2 and CO2 contents both decrease. With the increase of the H2 content in the gas, the direct reduction degree of iron gradually decreases and the volume shrinkage burden increases. Apparently, injecting gas into the blast furnace can prevent the theoretical combustion temperature from being too high and solve the contradiction between the upper cooling and lower heating of the blast furnace.
35
Zeng, Ke, Shi Hao Liu, Hong Chao Zhang, and Yan Ping Cui. "Effect and Circulating of IC Reactor Treating Straw-Washing Wastewater." Advanced Materials Research 881-883 (January 2014): 540–45. http://dx.doi.org/10.4028/www.scientific.net/amr.881-883.540.
Повний текст джерелаАнотація:
An IC reactor volume 6m3 was used to treat the straw-washing water produced in a pulping and papermaking mill in experiment. When loading rate was 3.34~6.28kgCOD/(m3·d) COD average removal rate was 28.14%, that was lower than COD average removal rate of sludge waking up stage (47.30%) and acclimation stage (51.14%), and also lower than COD removal rate (50~80%) of IC running well. Gas production rate of the reactor was 1.53~32.17L/h, and effluent VFA was 746.0~1211.0mg/L. So hydrolysis-acidification process was more appropriate than anaerobic process when treating the straw-washing water. Due to low concentration of the wastewater and less gas production, the inner circulatory system of the reactor produced discontinuous ascending flow. When gas production rate of the reactor was 12.00~54.55L/h, flow rate of lifting pipe was 1.20~12.86L/h, and the ratio of flow rate and gas production rate was 0.08~0.36. Down pipe produced intermittent backflow, backflow rate reached 518.4~725.1L/h.
36
Atkinson, David I., Oyvind Reksten, Gerald Smith, and Helge Moe. "High-Accuracy Wet-Gas Multiphase Well Testing and Production Metering." SPE Journal 11, no. 02 (June 1, 2006): 199–205. http://dx.doi.org/10.2118/90992-pa.
Повний текст джерелаАнотація:
Summary Dedicated wet-gas flowmeters are now commercially available for the measurement of gas and liquid flow rates and offer a more compact measurement solution than does the traditional separator approach. The interpretation models of traditional multiphase flowmeters emphasize the liquid rate measurements and have been used to well test and meter mostly liquid-rich flow streams. These models were not developed for the measurement of gas flow rates, particularly those of wet gas. A new interpretation is described that allows a traditional multiphase flowmeter to operate in a dual mode either as a multiphase meter or as a wet-gas meter in 90 to 100% gas. The new interpretation model was developed for a commercially available multiphase flowmeter consisting of a venturi and a dual-energy composition meter. This combination results in excellent predictions of the gas flow rate; the liquid rate prediction is made with acceptable accuracy and no additional measurements. The wet gas and low-liquid-volume-fraction interpretation model is described together with the multiphase flowmeter. Examples of applying this model to data collected on flow loops are presented, with comparison to reference flow rates. The data from the Sintef and NEL flow loops show an error (including the reference meter error) in the gas flow rate, better than ± 2% reading (95% confidence interval), at line conditions; the absolute error (including the reference meter error) in the measured total liquid flow rate at line conditions was better than ± 2 m3/h (< ± 300 B/D: 95% confidence interval). This new interpretation model offers a significant advance in the metering of wet-gas multiphase flows and yields the possibility of high accuracies to meet the needs of gas-well testing and production allocation applications without the use of separators. Introduction There has been considerable focus in recent years on the development of new flow-measurement techniques for application to surface well testing and flow-measurement allocation in multiphase conditions without separating the phases. This has resulted in new technology from the industry for both gas and oil production. Today, there are wet-gas flowmeters, dedicated to the metering of wet-gas flows, and multiphase meters, for the metering of multiphase liquid flows. The common approach to wet-gas measurement relates gas and liquid flows to a "pseudo-gas flow rate" calculated from the standard single-phase equations. This addresses the need for gas measurement in the presence of liquids and can be applied to a limit of liquid flow [or gas volume fraction, (GVF)], though the accuracy of this approach decreases with decreasing GVF. The accurate determination of liquid rates by wet-gas meters is restricted in range. The application and performance of multiphase meters has been well documented through technical papers and industry forums, and after several years of development is maturing (Scheers 2004). Some multiphase measurement techniques can perform better, and the meters provide a more compact solution, than the traditional separation approach. It is not surprising that the use of multiphase flowmeters has grown significantly, the worldwide number doubling in little over a 2-year period (Mehdizadeh et al. 2002). Multiphase-flowmeter interpretation emphasizes the liquid rate measurement, and the application of multiphase flowmeters has been predominantly for liquid-rich flow stream allocation and well testing.
37
Mertens, D. R., and P. J. Weimer. "Method for measuring gas production kinetics." BSAP Occasional Publication 22 (1998): 209–11. http://dx.doi.org/10.1017/s0263967x00032626.
Повний текст джерелаАнотація:
Methodology can play a critical rôle in the measurement of digestion kinetics, especially when the objective is to define kinetic parameters for use in formulating rations or modelling animal responses. Measurement of gas production kinetics provides the opportunity to evaluate the rate of digestion of the soluble, more rapidly fermenting fractions of foods but has the potential for being more sensitive to the in vitro procedure used. Differences among procedures that have little impact on digestion of dry matter after 48 h of incubation, may have dramatic effects on fermentation of soluble matter during the first 20 h. Our objective was to develop a method for measuring the kinetics of gas production that would minimize any detrimental effects associated with the in vitro system and provide estimates of digestion kinetics that can be used to both describe foods for ration formulation systems and provide parameters for models of ruminal digestion.
38
Ma, Yingrui, Shuxia Li, and Didi Wu. "Influence of Intrinsic Permeability on the Production Performance of Shenhu Hydrate Sediment through Depressurization." E3S Web of Conferences 118 (2019): 01008. http://dx.doi.org/10.1051/e3sconf/201911801008.
Повний текст джерелаАнотація:
Natural gas hydrate(NGH) is a clean resource with huge reserves. The depressurization method is an economical and effective exploitation method. In the process of depressurization, reservoir absolute permeability has an important influence on production results. Based on the data of Shenhu hydrate reservoirs, this paper established a depressurization production numerical simulation model. Then, the production performances such as pressure, temperature, gas production rate, cumulative gas production, and hydrate dissociation effect are all studied under different permeability conditions.study the change of reservoir pressure, gas production rate, cumulative gas production, reservoir temperature change and hydrate dissociation effect under different permeability conditions. Results show that higher permeability is conducive to the depressurization of hydrate reservoirs.
39
Uzun, Ilkay, Basak Kurtoglu, and Hossein Kazemi. "Multiphase Rate-Transient Analysis in Unconventional Reservoirs: Theory and Application." SPE Reservoir Evaluation & Engineering 19, no. 04 (May 18, 2016): 553–66. http://dx.doi.org/10.2118/171657-pa.
Повний текст джерелаАнотація:
Summary In unconventional reservoirs, production data are generally analyzed by use of rate-transient techniques derived from single-phase linear-flow models. Such linear-flow models use rate-normalized pressure, which is pressure drop divided by reservoir-flow rate vs. square root of time. In practice, the well-fluid production includes water, oil, and gas. The oil can be light oil, volatile oil, and gas/condensate as in the Bakken, Eagle Ford, and Barnett, respectively. Thus, single-phase analysis needs modification to account for production of fluid mixtures. In this paper, we present a multiphase-pressure-diffusivity equation to analyze multiphase flow in single- and dual-porosity models of unconventional reservoirs. Our approach is similar to the work presented by Perrine (1956); however, our approach has a theoretical foundation, whereas Perrine (1956) used pragmatic engineering analogy for constant flow rate in vertical wells only. In addition to oil, gas, and formation brine, our method accounts for gas/condensate production, and the flowback of the injected hydraulic-fracturing fluids. Overall, our proposed approach is more comprehensive than the single-phase models but maintains the simplicity of the conventional methods. Our paper includes diagnostic plots of rate-normalized well pressure for light oils and gas/condensates in unconventional reservoirs. Data from two Bakken and two Eagle Ford wells will be presented to demonstrate the usefulness of our approach. In addition to the mathematical analysis of flow-rate and pressure data, we will present the effect of well-stimulation and fluid-lift methods on the flow-rate characteristics of Bakken and Eagle Ford wells.
40
Wang, Chunzi, and Mingxiong Zhu. "Scenario Prediction of China’s Natural Gas Consumption and Carbon Emissions in the Next Ten Years." Frontiers of Economics in China 16, no. 3 (December 22, 2021): 569–87. http://dx.doi.org/10.54605/fec20210307.
Повний текст джерелаАнотація:
Based on Johansen Cointegration Test, this paper sheds light on the long-run equilibrium relationship between natural gas consumption, gas production, and GDP in China. Three different natural gas demand scenarios of low, medium and high rates in the next ten years are considered, and a Neural Network Autoregression Model is used to predict the future carbon dioxide emission. We conclude: (1) In all three scenarios, the growth rates of natural gas consumption are all higher than those of natural gas production, while the gap between demand and domestic supply will gradually turn broader and China will largely rely on imports ; (2) In the scenario of low-rate economic growth, natural gas consumption will grow slowly, and it will be difficult to realize the carbon emission reduction targets by 2030 due to low-rate substitution of natural gas for coal; (3) If medium-rate to high-rate economic growth sustains, coupled with rapid increase in natural gas consumption and production, China’s Carbon Emission Reduction Targets for 2030 can be achieved with high-rate substitution of natural gas for coal.
41
Xie, Weiyang, Jianfa Wu, Xuefeng Yang, Cheng Chang, and Jian Zhang. "Gas–Water Two-Phase Flow Characteristics and Flowback Evaluation for Shale Gas Wells." Water 14, no. 10 (May 20, 2022): 1642. http://dx.doi.org/10.3390/w14101642.
Повний текст джерелаАнотація:
The dynamic characteristics of shale gas wells are complexly affected by the gas–water two-phase flow. Based on the special flow mechanism of gas–water two-phase flow in shale gas reservoir, this paper establishes a mathematical model for gas–water two-phase flow in shale gas multi-stage fractured horizontal wells, introduces the eigenvalue method and orthogonal transformation, and obtains the analytical solution of the two-phase flow model. The gas–water two-phase flow rules and main influence factors of shale gas wells were identified, further combined with the flowback test characteristics and data of the shale gas wells in southern Sichuan, the characteristic parameters for the evaluation of the gas well flowback effect were determined, and an index system was established for the evaluation of shale gas well flowback. The analysis result shows that the shale gas well flowback effect has a good relationship with its production capacity, which is mainly reflected in the flowback characteristic parameters such as gas breakthrough time, gas breakthrough flowback rate, 30 d flowback rate, and maximum production flowback rate. The shale gas wells with lower flowback factors have a better production capacity than those with higher flowback factors. The flowback evaluation index system can accurately forecast the shale gas well production capacity in its initial stage, and furthermore offer guidance to promptly ascertaining the block development potential and formulating the development schemes.
42
Freiria, Lucien Bissi da, Joanis Tilemahos Zervoudakis, Nelcino Franciso de Paula, Luciano Da Silva Cabral, Luis Orlindo Tedeschi, Pedro Ivo José Lopes da Rosa e. Silva, Alan Carlos Barboza Melo, and Adriano Jorge Possamai. "Do fibrolytic, proteolytic and amylolytic enzymes influence the in vitro fermentation characteristics of forage?" Semina: Ciências Agrárias 39, no. 3 (May 4, 2018): 1143. http://dx.doi.org/10.5433/1679-0359.2018v39n3p1143.
Повний текст джерелаАнотація:
The effects of increasing doses of three exogenous enzymes preparations with fibrolytic activity (FIB - 0, 0.6, 1.2, 1.8, and 2.4 mg mL-1liquid volume incubated), amylolytic activity (AMZ - 0, 0.05, 0.10, 0.15, and 0.20 mg mL-1liquid volume incubated), and proteolytic activity (PRO - 0, 0.05, 0.10, 0.15, and 0.20 mg mL-1 liquid volume incubated ) on gas production (GP), kinetic parameters, and fermentation profile of Brachiaria brizantha cv. Marandu were evaluated using the in vitro gas production technique. Ruminal liquid was obtained from two rumen-cannulated Santa Inês sheep maintained on pasture. Accumulated gas production was measured during 96 hours of incubation, measured at 18 different time points. The determined parameters were pH, asymptotic gas production (mL g-1), rate of gas production (h-1), lag time (h), organic matter digestibility (OMD, g g-1 DM), metabolizable energy (ME, MJ kg-1 DM), and neutral detergent fiber digestibility (NDFD, mg g-1 DM). Increasing the FIB dose linearly increased (P < 0.05) the asymptotic gas production. However, the rate of gas production and the lag time showed linear decreases (P < 0.05). Addition of FIB also linearly increased (P < 0.05) the GP at all incubation times, as well as the OMD, NDFD and ME. Addition of AMZ linearly increased (P < 0.05) the asymptotic gas production, but GP linear increased (P < 0.05) only at the 6-hour and 12-hour time points. The rate of gas production and the lag time decreased linearly (P < 0.05) in response to increasing AMZ addition. Inclusion of PRO did not affect (P > 0.05) asymptotic gas production, but there was quadratic effect (P < 0.05) on the rate of gas production, the lag time, and the GP at the 6-hour and 12-hour time points. The OMD, NDFD and ME were not affected by PRO addition. Thus, fibrolytic, amylolytic and proteolytic enzymes are effective in reducing the lag time and increasing the in vitro gas production from Brachiaria Brizantha cv. Marandu forage, and fibrolytic enzymes improve the in vitro fermentation profile.
43
Mohammed, Mohammed Saeed, Dr Abdul Aali Al Dabaj, and Dr Samaher AbdilRassol Lazim. "Artificial Lift Design of Mishrif Formation in Nasiriyah Oil Field." Journal of Petroleum Research and Studies 9, no. 2 (June 23, 2019): 1–21. http://dx.doi.org/10.52716/jprs.v9i2.288.
Повний текст джерелаАнотація:
The possibility of improving the oil production rate for Mishrif formation in Nasiriyah oil field, located in Thi-Qar Governorate – southern province of Iraq, proposed in this paper. Electrical submersible pump (ESP) and gas lift techniques were applied to one well (NS-Y) in the studied reservoir. Firstly, the mathematical model has been built and validation has been done using PIPESIM software in order to select the best correlation (Duns & Ros correlation) for the pressure gradient calculation in the wellbore. The effect of decreasing reservoir pressure and increasing water cut on production rate has been studied through the evaluation of the well performance. The production rate was decreased to 1917 STB/D when reservoir pressure reached to 2750 psi, and flow rate decreased to 1210 at water cut 60%. Therefore, the artificial lift techniques were applied to increase the oil production rate. The result showed that Gas lift system contributed to increase production rate to (3198) STB/D at reservoir pressure equal to 2750 psi, while using the ESP system improved oil production rate to (2800) STB/D at reservoir pressure 2750 psi. The results also showed that gas lift system contributed to increase production rate to (3805) STB/D at water cut 60% and ESP raised the production rate to 3087 STB/D at water cut 60%. The comparison between them showed that the gas lift technique gave the highest production rate at different reservoir pressure and water cut.
44
Liu, Lei, Zhi Hua Fan, Qiang Xue, and Jiang Shan Li. "The P-V Modified Model and Experiment of Landfill Gas Generation Rate." Advanced Materials Research 512-515 (May 2012): 317–20. http://dx.doi.org/10.4028/www.scientific.net/amr.512-515.317.
Повний текст джерелаАнотація:
The Palos Verdes (P-V) modified model for gas generation rate was given, to resolve the supposition for critical point of the gas generation peak in the P-V model. The laboratory experiments of biolysis reaction with typical ratio of waste component (the organic fraction of readily degradation is 55%, 30%, and 15%, respectively) were conducted. At the first stage, the reaction coefficient k1 was equal to 0.01512, 0.00792 and 0.00756day-1, and the reaction coefficient k2 was equal to 0.0317, 0.0181 and 0.0145day-1, respectively ,at the second stage. And the initial production potential was equal to 5900, 2800, and 486 m3 /ton, respectively. The gas generation in the first stage was effected obviously by the waste component. The gas generation occurred in the first stage must be considered to evaluate the landfill gas production. Moreover, the reliability and practicability of the P-V modified model was approved by the better fitting from the simulation result and the testing data of the gas generation rate.
45
Widiyaningsih, Indah, Panca Suci Widiantoro, Suwardi Suwardi, and Riska Fitri Nurul Karimah. "RESERVOIR PERFORMANCE ANALYSIS USING MATERIAL BALANCE METHOD IN GAS FIELD." Journal of Petroleum and Geothermal Technology 2, no. 2 (November 28, 2021): 68. http://dx.doi.org/10.31315/jpgt.v2i2.5503.
Повний текст джерелаАнотація:
The RF reservoir is a dry gas reservoir located in Northeast java offshore that has been produced since 2018. The RF reservoir has produced 2 wells with cumulative production until December 2019 is 31.83 BSCF. In January 2018 the gas production rate from the two wells was 36 MMSCFD and the reservoir pressure at the beginning of production was 2449.5 psia, peak production occurred in April 2019 with a gas flow rate of 98 MMSCFD but in December 2019 the gas production rate from both wells decreased to 30 MMSCFD with reservoir pressure decreased to 1607.8 psia. Changes in gas flow rate and pressure in the RF reservoir will affect changes in reservoir performance, so it is necessary to analyze reservoir performance to determine reservoir performance in the future with the material balance method. Based on the results the initial gas in place (IGIP) is 80.08 BSCF. The drive mechanism worked on the RF reservoir until December 2019 was a depletion drive with a recovery factor up to 88% and a current recovery factor (CRF) is 40%. The remaining gas reserves in December 2019 is 39 BSCF and the reservoir will be made a production prediction until December 2032. Based on production predictions of the four scenarios, scenario 2 was chosen as the best scenario to develop the RF reservoir with a cumulative production is 66.1 BSCF and a recovery factor of 82.6%.
46
Kondrat, R. М., О. R. Kondrat, L. І. Khaidarova, and N. М. Hedzyk. "The Influence of Determining Factors on the Parameters of Gas-lift Operation of Flooded Gas Wells." Prospecting and Development of Oil and Gas Fields, no. 1(74) (March 31, 2020): 72–80. http://dx.doi.org/10.31471/1993-9973-2020-1(74)-72-81.
Повний текст джерелаАнотація:
The development of gas deposits at the final stage is usually complicated by watering production wells. With the advent of water in the formation product, the gas production rate decreases due to the decrease in the gas-saturated thickness of the reservoirs and the increase in pressure loss during movement of the liquid-gas mixture in the wellbore and flow lines as compared to the movement of gas only. Well operation is gradually becoming unstable, periodic with the subsequent cessation of natural flowing. The methods of operation of flooded wells are characterized. The use of the gas-lift method for the operation of flooded gas wells in depleted gas fields is justified. The effect of tubing diameter, wellhead pressure and water factor on the parameters of gas-lift operation of flooded wells is investigated. The research is carried out using the improved technique proposed by the authors and the PipeSim program for hypothetical (simulated) well conditions. The studies performed are presented in the form of graphical dependences of the production rate of reservoir gas, the minimum required gas production rate for the liquid to be taken from the bottom of the well to the surface, lift gas flow rate and bottomhole pressure on wellhead pressure, diameter of tubing and water factor. The research results indicate a significant coincidence of the values of the calculated parameters of the gas-lift operation of the watered well according to the proposed methods and the PipeSim program. Using the research results, it is possible to select the optimal diameter of the tubing string and evaluate the value of formation gas flow rate and gas-lift flow rates for various values of water factor and wellhead pressure.
47
Huang, Quan Hua, and Xing Yu Lin. "A new model for calculating the critical fluid carrying rate in inclined Wells." E3S Web of Conferences 213 (2020): 03009. http://dx.doi.org/10.1051/e3sconf/202021303009.
Повний текст джерелаАнотація:
In the preparation of gas production plan and the study of gas well proration we often judge the fluid carrying capacity of gas well by the critical fluid carrying rate of the gas well, and then adjust the production plan. At present, spherical droplet model and ellipsoidal droplet model are often used to calculate the fluid flow in gas Wells, but the spherical cap droplet model has not been concerned by relevant scholars. Therefore, we studied the application range of spherical cap droplet model, established relevant mechanical expressions, and finally obtained the formula for calculating the minimum critical liquid carrying rate of spherical cap droplet model. The results show that the spherical cap droplet model cannot be ignored in the conventional droplet model and has a wide range of applications. At the same time, the model is validated by combining with gas Wells of H gas reservoir, and the model has good applicability.
48
Musakaev, N. G., and S. L. Borodin. "GAS PRODUCTION FROM THE HYDRATE RESERVOIR AT NEGATIVE TEMPERATURES." Oil and Gas Studies, no. 5 (November 1, 2017): 80–85. http://dx.doi.org/10.31660/0445-0108-2017-5-80-85.
Повний текст джерелаАнотація:
The mathematical model of the process of gas hydrate decomposition information to gas and ice is pro-posed. This model takes into account the non-isothermal filtration flow of gas, the adiabatic cooling effect, real gas properties, and Joule-Thomson effect. The influence of bottom hole pressure, permeability of a porous medium, and hydrate saturation on the rate of gas production from the reservoir initially saturated with methane and its hydrate was analyzed.
49
Wahid, Abdul, and Muhamad Taufiq Hidayat. "Analysis of chemical volume and composition to overcome liquid loading in gas well." E3S Web of Conferences 67 (2018): 03009. http://dx.doi.org/10.1051/e3sconf/20186703009.
Повний текст джерелаАнотація:
Many problems often occur in producing natural gas from well. Due to the existence of water content in natural gas or water drive mechanism, liquid (especially water) is also produced from gas well, following natural gas production. When gas critical rate is higher than gas production rate due to reservoir pressure decline, it will cause liquid accumulation in the bottom of well, avoiding natural gas to be well lifted from well bottom to surface. It is liquid loading. Chemical injection of 0.4 liquid that consists of ethoxy sulphate, alkane sulphonate, and petroleum sulphonate is effective to overcome liquid loading in natural gas well thus causing an increase in natural gas production by 57%.
50
Chen, Lan, and Yu Heng Quan. "Effect of Gas Flow Rate on Degradation of 2,4-D with O3 and O3/H2O2." Advanced Materials Research 433-440 (January 2012): 221–26. http://dx.doi.org/10.4028/www.scientific.net/amr.433-440.221.
Повний текст джерелаАнотація:
The effect of gas flow rate on degradation of chlorinated phenoxy acetic acids herbicide 2,4-D(2,4-dichlorophenoxyacetic acid) in aqueous solution with O3 or O 3/H 2O2 process was investigated in a bubbling semi-batch reactor. The experiments were conducted to study the degradation rate constant, mass transfer condition, ozone consumption and formation of byproduct hydrogen peroxide at different gas flow rates. The results show that gas flow rate is a complicated parameter in the process. The contact time of gas and liquid phase varies with different gas flow rate, consequently ozone mass transfer condition changes with different gas flow rates. The production rate of ozone, amount of ozone in the end gas and ozone consumption during the degradation with ozonation and O 3/H2O2 process vary with different of gas flow rates. Hydrogen peroxide is a byproduct during the ozonation or O3/H2O2 process of 2,4-D. The production rate of hydrogen peroxide is also affected by the gas flow rate. In general gas flow rate has both positive and negative effect on the 2,4-D degradation.