scholarly journals Research on the method of repairing gas lift pipeline from FPSO Ruby - II to Pearl wellhead platform

2021 ◽  
Vol 62 (3a) ◽  
pp. 10-16
Author(s):  
Chuyen Viet Do ◽  
Thinh Van Nguyen ◽  
Dung Anh Hoang ◽  
Keyword(s):  
Pipeline System ◽  
Recovery Stage ◽  
Mechanical Methods ◽  
Secondary Recovery ◽  
Compressed Gas ◽  
The Cost ◽  
Gas Lift

Some offshore oilfields of Vietnam such as Bach Ho, Rong, Dai Hung, Ruby,… are at this moment in the secondary recovery stage. Gas lift production is one of the suitable methods in this period. Gas lift has proved itself as a more advantageous method in comparisons with other mechanical methods applied at Ruby oilfield. On the Pearl wellhead platform located in Ruby field, a gas lift system is installed to serve for the extraction of petroleum. The system is provided with compressed gas supplied from the FPSO Ruby II through a subsea 6 inches pipeline gas lift. For the sake of effective producing activity, it is a vital task to ensure the safety of this pipeline system during operations. In the case of failures, reparation should be applied immediately to minimize shutdown time and reduce the cost of troubleshooting. This article presents the “smart flange” technique to repair the gas lift pipeline system from the FPSO Ruby - II to the Pearl wellhead platform. Results of the work provide realistic knowledge to propose practical solutions to the maintenance and reparation of this system and thus, improve its operation.

Now Is the Time for Gas Lift To Live Up to Its Potential

2021 ◽  
Vol 73 (05) ◽  
pp. 21-27
Author(s):  
Stephen Rassenfoss
Keyword(s):  
Gas Injection ◽  
Oil Well ◽  
Variable Speed Drives ◽  
Well Production ◽  
Artificial Lift ◽  
New Thinking ◽  
Base Management ◽  
Pumping Units ◽  
The Cost ◽  
Gas Lift

Gas lift is one of the most popular ways to increase oil-well production, and it is no secret that it is an underperformer. Back in 2014, ExxonMobil reported that by creating a team of roving gas-lift experts it was able to add an average of 22% more output on several hundred wells where the gas injection had been optimized. Gains were expected because “wells do not remain the same over time; they change,” said Rodney Bane, global artificial-lift manager at ExxonMobil, in this JPT story covering the 2014 SPE Artificial Lift Conference and Exhibition (https://jpt.spe.org/paying-close-attention-gas-lift-system-can-be-rewarding). The problem with gas injection is that change is hard. Injection adjustment or repairs require either pulling the tubing to reach the injection mandrels or a wireline run. Those with good- producing wells, particularly offshore, need to weigh the possible gain against the cost and lost production during the job. Those managing more and more wells live with iffy data, injection systems prone to malfunction, horizontal wells prone to irregular flows, and a time-consuming process for calculating the proper injection rates. New approaches addressing those negatives have led a few big operators to try new systems designed to allow constant adjustments based on downhole data with electric control systems designed to be more reliable. Programmable digital controls raise an obvious question: How do you take advantage of that capability? Constantly updated injection data based on traditional evaluation methods is the first step. And new capabilities are inspiring new thinking about how injected gas lifts production and how to make it work more efficiently. Optimizing the process has not been a priority in gas lift. “It was a fairly imprecise thing. But the beauty of gas lift is it works even where it’s broken. It’s not a pump; it’s flow assurance,” said Brent Vangolen, surface and base management technology manager with Occidental. Occidental is among the early adopters of new gas-lift methods along with companies including Chevron, Shell, ExxonMobil, Petronas, and ADNOC. Vangolen expects the industry will follow. “Gas lift is going through the same transformation as rod pumps went through in the 60s and 70s,” he said. Back then, rod pump engineers began tracking changes in the load on the rod through each pump stroke by using dynamometer cards. That data was used to better program pump controls. “You went from egg timers on pumping units to full-blown optimization pumpoff controllers, variable speed drives … this huge infant technology that changed the rod pump space,” he said. Papers at last year’s SPE artificial lift conference covered the continuing digitization in rod lift and that gas lift was finally moving in that direction.

scholarly journals Comprehensive investigation of low salinity waterflooding in carbonate reservoirs

2021 ◽  
Author(s):  
M. Fouad Snosy ◽  
Mahmoud Abu El Ela ◽  
Ahmed El-Banbi ◽  
Helmy Sayyouh
Keyword(s):  
Oil Recovery ◽  
Carbonate Reservoirs ◽  
Rock Properties ◽  
Recovery Stage ◽  
Low Salinity ◽  
Water Composition ◽  
Secondary Recovery ◽  
Low Salinity Waterflooding ◽  
Tertiary Recovery ◽  
Incremental Oil Recovery

AbstractWaterflooding has been practiced as a secondary recovery mechanism for many years with no regard to the composition of the injected brine. However, in the last decade, there has been an interest to understand the impact of the injected water composition and the low salinity waterflooding (LSWF) in oil recovery. LSWF has been investigated through various laboratory tests as a promising method for improving oil recovery in carbonate reservoirs. These experiments showed diverse mechanisms and results. In this study, a comprehensive review and analysis for results of more than 300 carbonate core flood experiments from published work were performed to investigate the effects of several parameters (injected water, oil, and rock properties along with the temperature) on oil recovery from carbonate rock. The analysis of the results showed that the water composition is the key parameter for successful waterflooding (WF) projects in the carbonate rocks. However, the salinity value of the injected water seems to have a negligible effect on oil recovery in both secondary and tertiary recovery stages. The study indicated that waterflooding with optimum water composition can improve oil recovery up to 30% of the original oil in place. In addition, the investigation showed that changing water salinity from LSWF to high salinity waterflooding can lead to an incremental oil recovery of up to 18% in the tertiary recovery stage. It was evident that applying the optimum composition in the secondary recovery stage is more effective than applying it in the tertiary recovery stage. Furthermore, the key parameters of the injected water and rock properties in secondary and tertiary recovery stages were studied using Fractional Factorial Design. The results revealed that the concentrations of Mg2+, Na+, K+, and Cl− in the injected water are the greatest influence parameters in the secondary recovery stage. However, the most dominant parameters in the tertiary recovery stage are the rock minerals and the concentration of K+, HCO3−, and SO42− in the injected water. In addition, it appears that the anhydrite percentage in the carbonate reservoirs may be an effective parameter in the tertiary WF. Also, there are no clear relations between the incremental oil recovery and the oil properties (total acid number or total base number) in both secondary and tertiary recovery stages. In addition, the results of the analysis showed an incremental oil recovery in all ranges of the studied flooding temperatures. The findings of this study can help to establish guidelines for screening and designing optimum salinity and composition for WF projects in carbonate reservoirs.

Technical inspection as an inventory item of fixed assets in the accounting of a healthcare organization

2021 ◽  
pp. 6-21
Author(s):  
Lyudmila Viktorovna Sotnikova
Keyword(s):  
Surgical Instruments ◽  
Complex Object ◽  
Pipeline System ◽  
Medical Organization ◽  
Technical Inspection ◽  
Fixed Assets ◽  
Useful Life ◽  
Health Organization ◽  
The Cost ◽  
Cost Limit

The article considers the features of forming a new inventory object for Russian accounting — technical inspection of this object of fixed assets as part of a complex object of fixed assets of a medical organization. Such an inventory item as a technical inspection is formed in accordance with FSB 6/2020 “Fixed assets” if it meets such important criteria as the cost exceeding the cost limit set by each health organization in its accounting policy, as well as the useful life exceeding 12 months. The article presents an example of accounting for technical inspection on the example of such an object of fixed assets as a pipeline system of compressed medical gases, gases for driving surgical instruments and vacuum.

Weed management in onion: A review

2017 ◽  
Author(s):  
M. Dhananivetha ◽  
M. Mohammed Amnullah ◽  
P. Murali Arthanari ◽  
S. Mariappan
Keyword(s):  
Weed Control ◽  
Weed Management ◽  
Growth Period ◽  
Threshold Level ◽  
Weed Competition ◽  
Important Species ◽  
Bulb Formation ◽  
Mechanical Methods ◽  
Hand Weeding ◽  
The Cost

The bulbous vegetable onion Allium cepa Var. aggregatum L. (2n=16) is the most important species of Allium group and is regarded as the single most important vegetable spices as it forms an indispensable part of many diets, both vegetarian and non-vegetarian. Onion is valued for its bulbs having characteristic odour, flavor and pungency. Onion is regarded as a highly export oriented crop and earns a valuable foreign exchange for the country. Weeds are of great menace as they interfere with production of crop and add to the cost of cultivation. The reduction in crop yield has direct correlation with weed competition. Onion exhibits greater susceptibility to weed competition as compared to other crops due to its inherent characteristics such as their slow growth, small stature, shallow roots and lack of dense foliage. The effective weed control involves identification of weed flora, method of weed control and judicious combination of effective weed control methods. Hand weeding in onion is a common practice in India, but it is a tedious, expensive and time consuming task due to closer spacing and shallow root system. Non-availability of labourers during critical period of crop makes hand weeding difficult leading to heavy yield losses. Spraying of pre-emergence herbicides keeps the crop in weed free conditions during the early stages. At later stage, second flush of weeds will affect the bulb formation. Hand weeding helps to keep the weed population below economic threshold level throughout the crop growth period. Pre-emergence combined with hand weeding may be costly because of the reduced labour availability and higher labour cost. After bulb formation manual or mechanical methods of weed control will damage the bulb. Application of early post emergence may be helpful to reduce damage to the bulb, weed competition and cost of weeding. Hence a brief review was presented to find out the effect of different weed management method in onion.

Parallel Pipelining

1995 ◽  
Vol 117 (3) ◽  
pp. 446-449 ◽  
Author(s):  
D. D. Joseph ◽  
R. Bai ◽  
T. Y. Liao ◽  
A. Huang ◽  
H. H. Hu
Keyword(s):  
Water Flow ◽  
Parallel System ◽  
Continuous Operation ◽  
Pipeline System ◽  
Pressure Gradients ◽  
Viscous Material ◽  
Parallel Pipeline ◽  
Single Pipe ◽  
The Cost

In this paper we introduce the idea of parallel pipelining for water lubricated transportation of oil (or other viscous material). A parallel system can have major advantages over a single pipe with respect to the cost of maintenance and continuous operation of the system, to the pressure gradients required to restart a stopped system and to the reduction and even elimination of the fouling of pipe walls in continuous operation. We show that the action of capillarity in small pipes is more favorable for restart than in large pipes. In a parallel pipeline system, we estimate the number of small pipes needed to deliver the same oil flux as in one larger pipe as N = (R/r)α, where r and R are the radii of the small and large pipes, respectively, and α = 4 or 19/7 when the lubricating water flow is laminar or turbulent.

Reliability Based Pressure Containment Uprating

2013 ◽  
Author(s):  
Elie Dib ◽  
Sherif El-Gebaly ◽  
Frank Drennan
Keyword(s):  
Structural Reliability ◽  
Probabilistic Approach ◽  
Probability Of Failure ◽  
Operating Conditions ◽  
Current Status ◽  
Pipeline System ◽  
Design Life ◽  
Target Probability ◽  
Fit For Purpose ◽  
The Cost

Over the design life of long tiebacks, project requirements may change in order to accommodate new prospects. These new prospects may have design conditions exceeding those used for the rest of the field and the existing facilities may not be able to withstand the potential increases in pressure arising from new wells. For smaller and accidental increases, the existing system may be proven to be fit for purpose by using a probabilistic approach, or a structural reliability assessment. This approach may eventually reduce the cost of the new prospect by, for example, removing the need for an over-pressure protection system, or removing the need for a dedicated pipeline system. This paper investigates the potential increase in pressure capacity of a main pipeline for an accidental over-pressure condition using a structural reliability analysis and probabilistic approach using as-built data gathered from several projects. The variations on the as-built pipeline properties, the current status of the existing pipeline, and the corresponding operating conditions are taken into account using a Monte Carlo simulation. The results present a burst pressure with an indication of a safety factor and associated with a probability of failure. A comparison between the final results and the pipeline codes target probability of failure is also performed and presented as part of this paper.

scholarly journals Establishing Cratylia argentea in an Ultisol in the West of Acre, Southwestern Amazon, Brazil

2020 ◽  
Vol 8 (3) ◽  
pp. 289-294
Author(s):  
Antônio Marcos de Souza Aquino ◽  
Eduardo Pacca Luna Mattar ◽  
Luís Henrique Ebling Farinatti ◽  
Leandro Roberto Da Cruz ◽  
Alen Patric de Oliveira Costa ◽  
...  
Keyword(s):  
Reference Model ◽  
Humid Tropics ◽  
Direct Seeding ◽  
First Year ◽  
Average Height ◽  
The West ◽  
Planting Methods ◽  
Mechanical Methods ◽  
Planting Method ◽  
The Cost

Cratylia argentea is a multi-purpose shrub with potential as a source of protein for livestock, but is rarely used in production units. This study aimed to monitor the establishment of a stand of this plant in a sandy Ultisol (Red-Yellow Argisol), in an area of 4,000 m2 on a rural property in Cruzeiro do Sul, Acre, Brazil, comparing 2 planting methods: (i) transplanting seedlings (78 in total); and (ii) direct seeding (3,820 seeds in 1,910 pits). The existing pasture was sprayed with glyphosate before planting C. argentea. Subsequently, herbicide and mechanical methods were used to control weeds, while fertilizer was applied and the area was mulched. In the first year after planting, activities performed and inputs were recorded along with costs in order to create a reference model for those intending to cultivate this species in the humid tropics. At 10 months after planting, average height of plants was 162 cm (range 70‒240 cm) with no effect of planting method. Ninety-seven per cent of plants established from seedlings survived, while 81% of pits established from direct seeding in the field had surviving plants. The cost of establishing a hectare of C. argentea was US$ 1,654.17, with 85.8% of the cost for labor and only 14.2% for other inputs, although costs of producing seedlings and hand-planting them were not considered. Studies to develop planting systems using less labor seem warranted.

scholarly journals Multi-Objective Gas Lift Optimization using Elitist Non-Dominated Sorting Genetic Algorithm (NSGA-II)

2019 ◽  
Vol 8 (4) ◽  
pp. 9737-9740
Keyword(s):  
Production Rate ◽  
Production Cost ◽  
Gas Injection ◽  
Oil Production ◽  
Injection Rate ◽  
Nsga Ii ◽  
Wellhead Pressure ◽  
Multi Objective ◽  
The Cost ◽  
Gas Lift

In petroleum industry, gas lift optimization is the most important for evaluating the reservoir. By improving the gas lift operation we can save money and time which we spend on the reservoir for effective production. The mainly accepted scenario of gas lift is to maximize production by using minimized cost infrastructure. If the production rate is increased, then the cost of oil production also increases due to the increase in surface facilities and increase in cost of gas compression to higher pressures. The production rate and production cost during gas lift are mutually conflicting in nature i.e., if anyone desires to increase the oil production rate, then at the same time it is difficult to minimize the cost of production. Therefore, this is an ideal candidate for multi-objective optimization study, where production rate needs to maximized while minimizing the cost of production. The oil production rate is calculated using nodal analysis of inflow performance and outflow performance curve while the production cost is calculated using the brake horsepower requirement of the compressor. Oil production rate during a gas lift operation can be defined as a function of various factors like (i) depth of gas injection, (ii) gas injection rate (iii) gas lift injection pressure, (iv) wellhead pressures, (v) bottom hole pressure, (vi) tubing size, (vii) surface choke size/wellhead pressure. Production cost mainly depends on the cost of gas compression which further depends on the pressure up to which gas has to be compressed in the annulus so that the gas lift valve at the bottom of the well opens. The opening of gas lift valve depends on the bottom hole pressure in the tubing i.e. the density of mixture present inside the tubing. The multi-objective gas lift optimization is carried out using multi-objective evolutionary algorithms (EAs) that use non-dominated sorting called elitist non-dominated sorting genetic algorithm (NSGA-II). In this project, we aim to find the optimum values of the decision parameters i.e. gas injection rate and wellhead pressure, for which oil production rate would be maximized while minimizing the cost of oil production.

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