Developments in the Simulation and Design of Multiphase Pipeline Systems

Norris, H.L.; Fuchs, Pavel; Malnes, D.; Klemp, S.

doi:10.2118/14283-ms

Cited by 9 publications

(4 citation statements)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The experimental facility described by Norris et al33 in which the test section encompasses a long horizontal pipeline culminating in a riser, has been modified to introduce the gas and liquid phases at the base of the vertical riser, to minimize upstream effects. The test fluids used were nitrogen and naphtha (a mixture of liquid hydrocarbons) at pressures of 20 and 90 bar and a nominal temperature of 30°C.…”

Section: Experimental Arrangementmentioning

confidence: 99%

Two‐phase flow patterns in large diameter vertical pipes at high pressures

2007

View full text Add to dashboard Cite

in Wiley InterScience (www.interscience.wiley.com).The flow pattern characteristics for a mixture of naphtha and nitrogen in a 52-m high, 189-mm diameter vertical pipe at 20 and 90 bar are reported. Time varying, void fraction and pressure variations along the riser were measured. For the former, gamma densitometers were employed. It was found that the classic slug flow pattern was not present in these experiments. The observed flow patterns are classified as bubble, intermittent, semiannular, and annular. All the methods for flow pattern transitions in vertical two-phase flow tested against the present experiments give poor predictions. The identification and delineation of flow patterns using probability density function distribution of the cross-sectionally averaged void fraction is consistent with the methods of employing pressure gradient fluctuations and structure velocity. Gas superficial velocities: top, 0.21 m/s (intermittent), bottom, 1.0 m/s (semiannular). U GS 5 0.372m/s and U LS 5 0.072 m/s.Figure 15. Flow pattern transitions at: (a) 20 bar; (b) 90 bar.

show abstract

Section: Experimental Arrangementmentioning

confidence: 99%

Two‐phase flow patterns in large diameter vertical pipes at high pressures

2007

View full text Add to dashboard Cite

show abstract

“…In this study, OLGA 7 Licensed by Schlumberger group as a transient single phase and multiphase simulator was used to model the response of a pipeline system to leaks of different sizes and locations. OLGA is an Eulerian, transient, gas -liquid, pipe flow simulator developed in Norway (Norris III et al, 1985). A pvt file containing the fluid's compositional properties as defined in Table 1 was created using a PVTSIM software and this was used to model a single phase 100 m length pipe as described in Table 2.…”

Section: Leak Modelling Using Olga Simulatormentioning

confidence: 99%

Integrated Leak Detection in Gas Pipelines Using OLGA Simulator and Artificial Neural Networks

Afebu

Abbas

Nasr

et al. 2015

Day 1 Mon, November 09, 2015

View full text Add to dashboard Cite

Gas pipeline leakages do not only represent loss of valuable non-renewable resources but also a potential source of environmental pollution and fire disaster, thus making it very important to have a quick and accurate leak awareness scheme in pipeline systems. In a novel approach of providing industry with more reliable, friendly and cost effective technique in handling pipeline leakage especially in countries were pipeline vandalism has been widely reported. This require urgent detection and intervention, the potential of an Artificial Neural Network (ANN) in detecting and locating leaks from everyday flow line measurements was explored in this research paper. Pipeline responses under zero (no) leak condition, and realistic different leak conditions were simulated on a gas pipeline using OLGA simulator. Simulated leaks were seen to be characterized with unique flow rate, velocity, pressure and temperature signatures that were identifiable by the neural network. The network during training was able to learn the correlation between these signatures and the leak parameters and then use the learning in predicting and locating leaks from new signature data. The network predictions showed final RMSE values of 6.14 and 0.977 for the single and multiple leaks model respectively. The correlations between the actual and predicted leak sizes gave R values of 0.95 and 0.60 for the single and multiple leaks respectively while those of the actual and predicted leak locations were 0.97 and 0.96. The system was able to locate 90% of the induced leaks to a distance that is less than 10 m away from the actual leak locations while 62% of the ANN predicted leak sizes differed from the actual value by less than 50% of the actual leak size and the remaining 38% differed by about 65 -400% the actual sizes. This thus implies that the set has a better precision in predicting leak locations than predicting leak sizes. Based on obtained results, it can be said that with sufficiently large number of measurements, neural networks are of great potential in predicting and locating leaks. Results also showed that leak detectability tends to improve with increasing leak size and increasing distance from the source and the relatively low correlation obtained for the multiple leaks model can be attributed to the partial masking of smaller downstream leaks by larger upstream leaks.These characteristics of leaks are predominant to the countries with cases of vandalism, and could be a potential approach in handling pipe leaks.

show abstract

“…In addition, the last 230 ft upstream of the riser inlet, starting at 1,083 ft from the mixing point, may be dipped 1º or 2º down to introduce terrain slugging in the riser. 19 All parts are made of carbon steel. The two-phase flow from the riser enters the top separator where the initial gasliquid separation takes place.…”

Section: Flow Loops Around the World -mentioning

confidence: 99%

Design of a High-Pressure Research Flow Loop for the Experimental Investigation of Liquid Loading in Gas Wells

Fernández

Falcone

Teodoriu

2010

SPE Projects, Facilities &Amp; Construction

View full text Add to dashboard Cite

Liquid loading in producing gas wells is the inability of the produced gas to remove produced liquids from the wellbore. A review of existing flow loops worldwide revealed that specialized areas of research such as liquid loading in gas wells are still lacking dedicated test facilities. This project presents the design of a new dedicated facility to be located at the TowerLab at the Richardson building with adequate operating conditions to reproduce the flow regimes encountered prior to and after the onset of liquid loading in gas wells. The facility consists of a compressed air system, pipelines for air and water, a pressure vessel containing glass beads, an injection manifold, and flow control and monitoring devices.Our results show that three compressors working in parallel is the most technical and economic configuration for the TowerLab based on the overall costs provided by the supplier, the footprint but most importantly the flexibility. The design of the pressure vessel required a cylindrical body with top and bottom welded-flat head covers with multiple openings to minimize its weight. The pipelines connecting major equipment and injection manifold located at the pressure vessel were selected based on the superficial velocities for air and water. These values also showed the need for independent injection using two manifolds instead of commingling flow through a tee joint. The use of digital pressure gauges with an accuracy of 0.05 to 25% and coriolis or vortex meters to measure air flowrate is also suggested.

show abstract

Developments in the Simulation and Design of Multiphase Pipeline Systems

Cited by 9 publications

References 3 publications

Two‐phase flow patterns in large diameter vertical pipes at high pressures

Two‐phase flow patterns in large diameter vertical pipes at high pressures

Integrated Leak Detection in Gas Pipelines Using OLGA Simulator and Artificial Neural Networks

Design of a High-Pressure Research Flow Loop for the Experimental Investigation of Liquid Loading in Gas Wells

Contact Info

Product

Resources

About