PREDICTION OF CONDENSATE FLOW RATES IN LARGE DIAMETER HIGH PRESSURE WET GAS PIPELINES

1978 ◽  
Vol 18 (1) ◽  
pp. 171 ◽  
Author(s):  
R. S. Cunliffe
Keyword(s):  
High Pressure ◽  
Residence Time ◽  
Flow Rate ◽  
Large Diameter ◽  
Operating Pressure ◽  
Gas Pipelines ◽  
Liquid Holdup ◽  
Wet Gas ◽  
Exploration And Production ◽  
Demand Changes

Esso Australia Ltd. operates two offshore gas platforms for Esso Exploration and Production Australia Inc. and Hematite Petroleum Pty. Ltd. in the Gippsland Basin. Gas and condensate from the Marlin platform flow to the gas plant near Sale, Victoria through a 67 mile, 20 inch pipeline. Gas and condensate from the Barracouta platform flow to the plant through a 30 mile, 18 inch pipeline. Average flowing pressure is 1300 psig. Condensate: gas ratios are 65 bbl/MMscf for Marlin and 15 bbl/MMscf for Barracouta.As these platforms are the only source of supply for the city of Melbourne, gas rates are changed to match gas demand. Changes in gas rate are accompanied by changes in condensate flow. From consideration of liquid holdup and liquid residence time, a method of predicting the condensate flow rate resulting from gas rate change was developed.A controlled run was made to test the prediction. After holding the Marlin gas rate steady at 150 MMscfd for 50 hours to reach equilibrium holdup conditions, the rate was increased to 250 MMscfd and held at this rate for 26 hours to reach equilibrium conditions again. The condensate flow rate out of the pipeline was monitored continually.The Marlin pipeline test demonstrated that changes in condensate flow rate resulting from changes in gas rate in high pressure wet gas pipelines can be predicted within 15 per cent of actual rates using liquid holdup and liquid residence time as input data. In the absence of holdup data from pipeline pigging, Eaton's correlation will provide good values for holdup for wet gas pipelines with operating pressure up to 1500 psig and which traverse relatively flat topography.This work has application in the sizing of liquid surge capacity required to receive condensate from high pressure wet gas pipelines. In many cases, investment in slug catcher facilities can be greatly reduced without risk of overfilling with liquid.

Application of High-Grade Steels to Onshore Natural Gas Pipelines Using Reliability-Based Design Method

2006 ◽  
Author(s):  
Joe Zhou ◽  
Brian Rothwell ◽  
Wenxing Zhou ◽  
Maher Nessim
Keyword(s):  
High Pressure ◽  
Wall Thickness ◽  
Design Method ◽  
Large Diameter ◽  
Economic Assessment ◽  
High Grade ◽  
Gas Pipelines ◽  
Natural Gas Pipelines ◽  
Reliability Based Design ◽  
Design Factors

Two example onshore gas pipelines were designed using a reliability-based approach. The first example (1219 mm, 17.2 MPa) represents a high-pressure large-diameter pipeline; the second example has a smaller diameter (762 mm) and lower pressure (9.9 MPa). Three steel grades (X70, X80 and X100) were used to develop three design solutions for each example. The wall thickness-related life cycle costs of the designs were evaluated. The design outcomes show that the reliability targets for both examples can be met using X100 steels and high equivalent design factors (0.93 for the first example and 0.9 for the second example). Moreover, ruptures and excessive plastic deformation of a defect free pipe were found to be insignificant integrity threats even when the design uses X100 and relatively high equivalent design factors such as 0.85 and 0.9. The economic assessment results show that the X100 design is the most economical option for the high-pressure large-diameter example. However, using X100 does not show a clear economic advantage over using X80 for the second example mainly because the wall thickness for the design using X100 is governed by the maximum D/t ratio constraint. The study also demonstrates the advantages of the reliability-based approach as a valuable tool in assessing the feasibility and potential benefits of using high-grade steels on a pipeline project.

Liquid Holdup in Wet-Gas Pipelines

1987 ◽  
Vol 2 (01) ◽  
pp. 36-44 ◽  
Author(s):  
K. Minami ◽  
J.P. Brill
Keyword(s):  
Gas Pipelines ◽  
Liquid Holdup ◽  
Wet Gas

scholarly journals Theoretical and Experimental Studies of a Digital Flow Booster Operating at High Pressures and Flow Rates

Processes ◽  
2020 ◽  
Vol 8 (2) ◽  
pp. 211 ◽  
Author(s):  
Chenggang Yuan ◽  
Vinrea Lim Mao Lung ◽  
Andrew Plummer ◽  
Min Pan
Keyword(s):  
Energy Efficiency ◽  
High Pressure ◽  
Flow Rate ◽  
High Energy ◽  
Control Flow ◽  
Fluid Power ◽  
Analytical Models ◽  
Operating Pressure ◽  
Hydraulic Systems ◽  
Flow Rates

The switched inertance hydraulic converter (SIHC) is a new technology providing an alternative to conventional proportional or servo-valve-controlled systems in the area of fluid power. SIHCs can adjust or control flow and pressure by means of using digital control signals that do not rely on throttling the flow and dissipation of power, and provide hydraulic systems with high-energy efficiency, flexible control, and insensitivity to contamination. In this article, the analytical models of an SIHC in a three-port flow-booster configuration were used and validated at high operating pressure, with the low- and high-pressure supplies of 30 and 90 bar and a high delivery flow rate of 21 L/min. The system dynamics, flow responses, and power consumption were investigated and theoretically and experimentally validated. Results were compared to previous results achieved using low operating pressures, where low- and high-pressure supplies were 20 and 30 bar, and the delivery flow rate was 7 L/min. We concluded that the analytical models could effectively predict SIHC performance, and higher operating pressures and flow rates could result in system uncertainties that need to be understood well. As high operating pressure or flow rate is a common requirement in hydraulic systems, this constitutes an important contribution to the development of newly switched inertance hydraulic converters and the improvement of fluid-power energy efficiency.

scholarly journals MODELING OF GAS-DYNAMIC PROCESSES IN THE ELEMENTS OF IMPULSE EJECTOR

2021 ◽  
pp. 66-72
Author(s):  
G. O. Voropaiev ◽  
Ia. V. Zagumennyi ◽  
N. V. Rozumnyuk
Keyword(s):  
Numerical Simulation ◽  
High Pressure ◽  
Flow Rate ◽  
Gas Flow ◽  
Dynamic Processes ◽  
Stable Operation ◽  
Operating Pressure ◽  
Gas Generator ◽  
Gas Dynamic ◽  
Ejector Nozzle

The paper presents the numerical results on gas-dynamic processes in various elements of the impulse ejector, including pre-chamber, supersonic nozzle and mixing chamber, to determine optimal geometric parameters providing the given flow rate characteristics. At an extra-high pressure of the ejecting gas (>100 bar) it is impossible to create a nozzle design with continuously changing cross-sectional area and limited nozzle length. So, it is necessary to place a pre-chamber between the gas generator and the ejector nozzle for throttling full gas pressure. In order to optimize the pre-chamber parameters in the ejector with discrete holes of the gas generator and the operating pressure in the range of 400÷1000 bar, a series of calculations were performed to determine the pre-chamber parameters, ensuring stable operation of the supersonic annular nozzle at the high pressure of 35÷45 bar and the flow rate of 0.5÷0.6 kg/s. 3D numerical simulation of the gas flow into the pre-chamber through the gas generator holes shows the degree of the flow pattern non-uniformity in the pre-chamber at the ejector nozzle inlet is quite low. This justifies the numerical simulation of gas flow in the ejector in axisymmetric formulation and allows restricting the number of the gas generator holes without inducing significant non-uniformity in the azimuthal direction.

scholarly journals Creation of start-of-the-art steels and technology of large diameter pipes production for oil and gas pipelines

2019 ◽  
Vol 75 (4) ◽  
pp. 497-506
Author(s):  
Yu. D. Morozov ◽  
M. Yu. Matrosov ◽  
B. F. Zin’ko
Keyword(s):  
Oil And Gas ◽  
Large Diameter ◽  
Operating Pressure ◽  
Gas Pipelines ◽  
Oil Pipelines ◽  
Large Diameter Pipes ◽  
High Level ◽  
Pipe Manufacturing ◽  
External Coating ◽  
Steel Works

The pipelines are one of most important section of the fuel and energy complex of Russia. About 75% of them are presented by gas pipelines of large diameter (1020–1420 mm) for the operating pressure up to 7.4 MPa. CNIIchermet after I.P. Bardin put a big contribution into creation of pipe steels and mastering of technologies for their production at steel-works of Russia. The Institute in cooperation with leading steels-works developed an array of pipe steel, which are successfully used at construction of modern gas and oil pipelines. Tendencies of requirements increasing to characteristics of steels for large diameter pipes for pipelines considered, creation stages of grade range of steels and technology of rolled products production analyzed. Main technological requirements for achieving mechanical properties high level determined. It was shown, that K60–K65 strength class steels meet requirements to northern pipelines for a pressure up to 11.8 MPa, to thick walled underwater pipelines for a pressure of 25.0 MPa and to pipes for seismic arears. Steel-works and pipe-manufacturing plant of Russia provide the production of longitudinal-welded pipes with wall thickness up to 40–60 mm with anticorrosion external coating and smooth internal coating.

Top-of-Line Corrosion Control in Large Diameter Wet Gas Pipelines

2009 ◽  
Author(s):  
Dylan Pugh ◽  
Stefanie Asher ◽  
Nader Berchane ◽  
Jiyong Cai ◽  
William J. Sisak ◽  
...  
Keyword(s):  
Large Diameter ◽  
Corrosion Control ◽  
Gas Pipelines ◽  
Wet Gas

A Model To Predict Liquid Holdup and Pressure Gradient of Near-Horizontal Wet-Gas Pipelines

2007 ◽  
Vol 2 (02) ◽  
pp. 1-8 ◽  
Author(s):  
Yongqian Fan ◽  
Qian Wang ◽  
Hong-Quan Zhang ◽  
Thomas John Danielson ◽  
Cem Sarica
Keyword(s):  
Pressure Gradient ◽  
Gas Pipelines ◽  
Liquid Holdup ◽  
Wet Gas

Design Challenges of Gas Export Pipelines for Pre-Salt Area Offshore Brazil

2013 ◽  
Author(s):  
Rafael F. Solano ◽  
Fábio B. de Azevedo ◽  
Eduardo Oazen
Keyword(s):  
Large Diameter ◽  
External Pressure ◽  
Economic Feasibility ◽  
Design Parameters ◽  
Brazilian Coast ◽  
Gas Pipelines ◽  
Design Code ◽  
Exploration And Production ◽  
Engineering Best Practices ◽  
Pipeline Wall

Recently the pre-salt development is a great challenge for Petrobras regarding the offshore exploration and production activities. The pre-salt area comprises several ultra-deepwater fields located far off the Brazilian coast. In order to flow the produced gas of these pre-salt fields, Petrobras has planned to install large diameter gas export pipelines as trunklines. The design of large diameter gas pipelines in ultra-deepwater of about 2200m has hydrostatic collapse and installation loadings being the major issues to be faced by the technical team. Reduction of pipeline wall thicknesses may improve the technical and economic feasibility of its installation in ultra-deepwater and sometimes can also increase the number of laying barges / vessels able to perform the installation. However, reduction in wall thickness is only feasible if the pipeline integrity under external pressure as well as under combined loadings is ensured in accordance with the applicable design code and the engineering best practices. This paper presents the assessment of some design parameters able to reduce the wall thicknesses along the pipeline length, while keeping the commitment to the engineering good practices and complying with all requirements of the DNV-OS-F101 design code. In order to illustrate the assessment, this paper presents results of two gas pipelines designed in accordance with DNV standards, one of them being optimized. The benefits of this optimization are emphasized in this work.

Towards a Numerical Design Tool for Composite Crack Arrestors on High Pressure Gas Pipelines

2010 ◽  
Author(s):  
F. Van den Abeele ◽  
L. Amlung ◽  
M. Di Biagio ◽  
S. Zimmermann
Keyword(s):  
High Pressure ◽  
Large Scale ◽  
Steel Wire ◽  
Large Diameter ◽  
High Strength ◽  
Tensile Tests ◽  
Design Tool ◽  
Pipe Material ◽  
Gas Pipelines ◽  
Numerical Design

One of the major challenges in the design of ultra high grade (X100) high pressure gas pipelines is the identification of a reliable crack propagation strategy. Ductile fracture propagation is an event that involves the whole pipeline and all its components, including valves, fittings, flanges and bends. Recent research results have shown that the newly developed high strength large diameter gas pipelines, when operated at severe conditions (rich gas, low temperatures, high pressure), may not be able to arrest a running ductile crack through pipe material properties. Hence, the use of crack arrestors is required in the design of safe and reliable pipeline systems. A conventional crack arrestor can be a high toughness pipe insert, or a local joint with higher wall thickness. Steel wire wrappings, cast iron clamps or steel sleeves are commonly used non-integral solutions. Recently, composite crack arrestors have enjoyed increasing interest from the industry as a straightforward solution to stop running ductile cracks. A composite crack arrestor is made of (glass) fibres, dipped in a resin bath and wound onto the pipe wall in a variety of orientations. In this paper, the numerical design of composite crack arrestors will be presented. First, the properties of unidirectional glass fibre reinforced epoxy are measured and the micromechanic modelling of composite materials is addressed. Then, the in-use behaviour of pipe joints with composite crack arrestors is covered. Large-scale tensile tests and four point bending tests are performed and compared with finite element simulations. Subsequently, failure measures are introduced to predict the onset of composite material failure. At the end, the ability of composite crack arrestors to arrest a running fracture in a high pressure gas pipeline is assessed.

scholarly journals Effect of Liquid Flow Rate and Amine Concentration on CO2 Removal from Natural Gas at High Pressure Operation in Packed Absorption Column

2015 ◽  
Vol 773-774 ◽  
pp. 1291-1295 ◽  
Author(s):  
Hairul Nazirah Abdul Halim ◽  
Mohd Shariff Azmi ◽  
Mohammad Azmi Bustam
Keyword(s):  
High Pressure ◽  
Natural Gas ◽  
Flow Rate ◽  
Liquid Flow ◽  
Liquid Flow Rate ◽  
Ghg Emissions ◽  
Offshore Platforms ◽  
Operating Pressure ◽  
Absorption Column ◽  
Absorption Performance

Greenhouse gas (GHG) emissions such as carbon dioxide (CO2) and methane (CH4) from oil and natural gas operation at offshore platforms have significant contribution to global warming. The reduction of these GHG emissions is possible through CO2 capture technology. This study reports the absorption performance of monoethanolamine (MEA) for the removal of CO2 from natural gas (NG) at high pressure conditions. The absorption experiments were performed in an absorption column packed with Sulzer Metal Gauze Packing at 5.0 MPa operating pressure. The absorption performance was evaluated in terms of CO2 removal (%) with liquid flow rate ranging from 1.81 to 4.51 m3/m2.h and MEA concentration of 1.0 - 4.0 kmol/m3. It was found that CO2 removal (%) had increased with increasing liquid flow rate and MEA concentration.

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