scholarly journals Numerical Simulation of the Minimum Insulation Thickness to Thermally Design a Subsea Pipeline Carrying an Oil and Gas Flow

2021 ◽  
Vol 39 (3) ◽  
pp. 763-774
Author(s):  
Prosper Gopdjim Noumo ◽  
Donatien Njomo ◽  
Kevin Zepang Nana ◽  
Leonard Ribot Chuisseu Nguewo
Keyword(s):  
Gas Flow ◽  
Oil And Gas ◽  
Flow Assurance ◽  
Fluid Temperature ◽  
Flowing Fluid ◽  
Insulating Material ◽  
Subsea Pipeline ◽  
Thermal Insulating ◽  
Pressure Profiles ◽  
Insulation Thickness

This paper considered an existing subsea pipeline transporting an oil and gas flow, and proposed to find the best thermal insulating material and the required thickness of insulation necessary to meet an output temperature of 40℃ and a pressure of 2.4MPa so as to avoid flow assurance issues. MATLAB and PIPESIM software were employed to run the simulations of the temperature and pressure profiles along the considered pipeline. Data used for the simulations were obtained from open literature. Results obtained from our simulations in MATLAB are validated using PIPESIM software, measured values and prediction model from literature. The temperature model was then used to thermally design an insulation thickness for the 50 km long pipeline using three insulating materials which are: black aerogel, polyurethane and calcium silicate. Results from the analysis showed that the black Aerogel material with a critical thickness of 10.16 cm is most effective to satisfy the criterion design. The effect of the selected insulating material was also investigated on the phase envelop. Results shows that for proper insulation thickness the flowing fluid temperature can be maintained at a temperature above which no flow assurance issues can be observed.

scholarly journals Flow Assurance in Subsea Pipeline Design - A Case Study of Ghana’s Jubilee and TEN Fields

2019 ◽  
Vol 19 (1) ◽  
pp. 72-85
Author(s):  
S. A. Marfo ◽  
P. Opoku Appau ◽  
J. Acquah ◽  
E. M. Amarfio
Keyword(s):  
Flow Rate ◽  
Hydrate Formation ◽  
Flow Assurance ◽  
Processing Plant ◽  
Subsea Pipeline ◽  
Gas Processing ◽  
Parallel Pipeline ◽  
Exploration And Production ◽  
Insulation Thickness ◽  
Pipeline Design

The increasing exploration and production activities in the offshore Cape Three Point Blocks of Ghana have led to the discovery and development of gas condensate fields in addition to the oil fields which produce significant amount of condensate gas. These discoveries require pipelines to transport the fluids avoiding hydrates and wax formation. This paper focuses on subsea pipeline design using Pipesim software that addresses flow assurance problems associated with transporting condensate gas from the Jubilee and TEN Fields to the Atuabo Gas Processing Plant. It also considered an alternate design that eliminates the need for capacity increase of flowlines for the futuristic highest projected flow rates in 2030. The design comprises of two risers and two flowlines. Hydrate formation temperature was determined to be 72.5 ˚F at a pressure of 3 000 psig. The insulation thickness for flowlines 1 and 2 were determined to be 1.5 in. and 2 in. respectively. The pipe size for flowlines 1 and 2 were determined to be 12 in. and 14 in. respectively. The maximum designed flow rate was determined to be 150 MMSCFD. To meet the highest projected flow rate of 700 MMSCFD in the year 2030 at the processing plant, a 16 in. ID pipeline of 44 km length was placed parallel to the 12 in. ID flowline 1. This parallel pipeline increased the designed flow rate by approximately 4.7 times (705 MMSCFD). The alternate design employs 18 in. and 20 in. ID pipes for flowlines 1 and 2 respectively. Keywords: Condensate Gas; Flowline; Flow Assurance; Hydrate; Pipesim

Quantitatively Assessing Hydrate-Blockage Development During Deepwater-Gas-Well Testing

SPE Journal ◽  
2018 ◽  
Vol 23 (04) ◽  
pp. 1166-1183 ◽  
Author(s):  
Zhiyuan Wang ◽  
Yang Zhao ◽  
Jianbo Zhang ◽  
Xuerui Wang ◽  
Jing Yu ◽  
...  
Keyword(s):  
Water Depth ◽  
Gas Flow ◽  
Oil And Gas ◽  
Management Strategies ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Flow Assurance ◽  
Well Testing ◽  
Gas Well ◽  
Hydrate Layer

Summary Hydrate-associated problems pose a key concern to the oil and gas industry when moving toward deeper-offshore reservoir development. A better understanding of hydrate-blockage-development behavior can help flow-assurance engineers develop more-economical and environmentally friendly hydrate-management strategies for deepwater operations. In this work, a model is proposed to describe the hydrate-blockage-formation behavior in testing tubing during deepwater-gas-well testing. The reliability of the model is verified with drillstem-testing (DST) data. Case studies are performed with the proposed model. They indicate that hydrates form and deposit on the tubing walls, creating a continuously growing hydrate layer, which narrows the tubing, increases the pressure drop, and finally results in conduit blockage. The hydrate-layer thickness is nonuniform. At some places, the hydrate layer grows more quickly, and this is the high-blockage-risk region (HBRR). The HBRR is not located where the lowest ambient temperature is encountered, but rather at the position where maximum subcooling of the produced gas is presented. As an example case—a deepwater gas well with a water depth of 1565 m and a gas-production rate of 45 × 104 m3/d—the hydrate blockage first forms at the depth of 150 m. In the section with a depth from 50 to 350 m, hydrates deposit more rapidly and this is the HBRR. As the water depth increases and/or the gas-flow rate decreases, the HBRR becomes deeper. Inhibitors can delay the occurrence of hydrate blockage. The hydrate problems can be handled with a smaller amount of inhibitors during deepwater well-testing operations. This work provides new insights for engineers to develop a new-generation flow-assurance technique to handle hydrate-associated problems during deepwater operations.

scholarly journals Research on pipeline and flow assurance solutions of oil and gas transportation from Diamond WHP to FPSO Ruby II

2021 ◽  
Vol 62 (2) ◽  
pp. 65-78
Author(s):  
Thinh Van Nguyen ◽  
Chinh Duc Nguyen ◽  
Truong Hung Trieu ◽  
Keyword(s):  
Pour Point ◽  
Oil And Gas ◽  
Flow Assurance ◽  
Wax Deposition ◽  
Steady State Condition ◽  
Subsea Pipeline ◽  
Offshore Production ◽  
Transportation Process ◽  
Potential Risks ◽  
Simulation Results

In offshore production of oil and gas, transporting products by subsea pipeline always has potential risks affecting the efficiency of the transportation process. For the Diamond oilfield, the process of gathering products and transportation is carried out according to a closed scheme in which the exploited products are preliminarily treated. The separated oil is transported to FPSO Ruby - II while the separated gas passed through the air compressor to increase pressure and then used for gaslift production. In fact, the oil produced at the Diamond oilfield has a high paraffin content, which causes difficulties during transportation. Therefore, the study on flow assurance to ensure the transportation of oil and gas from the Diamond oilfield to the FPSO Ruby - II is imperative. This paper presents the results of the research on flow assurance to maintain the safety of the transportation basing on the analysis of field data and the capability of the current subsea pipeline in comparison with the data gained from models carried out with OLGA software. The results show that the rate of wax deposition at normal steady state condition is relatively low. In addition, the thickness of wax deposition build - up is relatively small by simulation results. However, due to low temperature of transported oil which is lower than pour point temperature, a freeze layer will form on the surface of the pipeline. Therefore, regular pigging is considered the most effective way to remove wax.

A Novel Poly(Ionic Liquid) as the Thermal Insulating Material

2020 ◽  
Vol 13 (3) ◽  
pp. 241-247
Author(s):  
Wenxin Wei ◽  
Guifeng Ma ◽  
Hongtao Wang ◽  
Jun Li
Keyword(s):  
Thermal Conductivity ◽  
Ionic Liquid ◽  
Glass Transition ◽  
Transition Temperature ◽  
Glass Transition Temperature ◽  
Flame Resistance ◽  
Insulating Material ◽  
Low Thermal Conductivity ◽  
Thermal Insulating ◽  
Poly Ionic Liquid

Objective: A new poly(ionic liquid)(PIL), poly(p-vinylbenzyltriphenylphosphine hexafluorophosphate) (P[VBTPP][PF6]), was synthesized by quaternization, anion exchange reaction, and free radical polymerization. Then a series of the PIL were synthesized at different conditions. Methods: The specific heat capacity, glass-transition temperature and melting temperature of the synthesized PILs were measured by differential scanning calorimeter. The thermal conductivities of the PILs were measured by the laser flash analysis method. Results: Results showed that, under optimized synthesis conditions, P[VBTPP][PF6] as the thermal insulator had a high glass-transition temperature of 210.1°C, high melting point of 421.6°C, and a low thermal conductivity of 0.0920 W m-1 K-1 at 40.0°C (it was 0.105 W m-1 K-1 even at 180.0°C). The foamed sample exhibited much low thermal conductivity λ=0.0340 W m-1 K-1 at room temperature, which was comparable to a commercial polyurethane thermal insulating material although the latter had a much lower density. Conclusion: In addition, mixing the P[VBTPP][PF6] sample into polypropylene could obviously increase the Oxygen Index, revealing its efficient flame resistance. Therefore, P[VBTPP][PF6] is a potential thermal insulating material.

Coal tar pitch based carbon foam for thermal insulating material

2016 ◽  
Vol 169 ◽  
pp. 95-98 ◽  
Author(s):  
Yanli Wang ◽  
Ziguo He ◽  
Liang Zhan ◽  
Xiang Liu
Keyword(s):  
Coal Tar ◽  
Carbon Foam ◽  
Coal Tar Pitch ◽  
Insulating Material ◽  
Thermal Insulating

Managing Deepwater Flow Assurance: Unique Riser Design Allows Dual Annuli Thermal Insulating Fluid Installation

2005 ◽  
Author(s):  
Paul H. Javora ◽  
Xiaolan Wang ◽  
Jack Burman ◽  
Kevin Dale Renfro ◽  
Michael Andrew Weaver ◽  
...  
Keyword(s):  
Flow Assurance ◽  
Thermal Insulating ◽  
Riser Design

Radiation and Convection Heat Transfer in a Porous Bed

1968 ◽  
Vol 90 (1) ◽  
pp. 51-54 ◽  
Author(s):  
W. A. Beckman
Keyword(s):  
Heat Transfer ◽  
Heat Flux ◽  
Collection Efficiency ◽  
Convection Heat Transfer ◽  
Heat Fluxes ◽  
Fluid Temperature ◽  
Radiation Heat ◽  
Radiation Heat Flux ◽  
Flowing Fluid ◽  
Porous Bed

The one-dimensional steady-state temperature distribution within an isotropic porous bed subjected to a collimated and/or diffuse radiation heat flux and a transparent flowing fluid has been determined by numerical methods. The porous bed was assumed to be nonscattering and to have a constant absorption coefficient. Part of the radiation absorbed by the porous bed is reradiated and the remainder is transferred to the fluid by convection. Due to the assumed finite volumetric heat transfer coefficient, the bed and fluid have different temperatures. A bed with an optical depth of six and with a normal incident collimated radiation heat flux was investigated in detail. The radiation incident on the bed at the fluid exit was assumed to originate from a black surface at the fluid exit temperature. The investigation covered the range of incident diffuse and collimated radiation heat fluxes expected in a nonconcentrating solar energy collector. The results are presented in terms of a bed collection efficiency from which the fluid temperature rise can be calculated.

scholarly journals Multiphase gas-flow model of an electrical submersible pump

2018 ◽  
Vol 73 ◽  
pp. 29
Author(s):  
Diana Marcela Martinez Ricardo ◽  
German Efrain Castañeda Jiménez ◽  
Janito Vaqueiro Ferreira ◽  
Pablo Siqueira Meirelles
Keyword(s):  
Gas Flow ◽  
Oil And Gas ◽  
Learning Algorithm ◽  
Estimation Error ◽  
Oil And Gas Industry ◽  
Support Vector ◽  
System Response ◽  
Submersible Pump ◽  
Two Phase ◽  
Electrical Submersible Pump

Various artificial lifting systems are used in the oil and gas industry. An example is the Electrical Submersible Pump (ESP). When the gas flow is high, ESPs usually fail prematurely because of a lack of information about the two-phase flow during pumping operations. Here, we develop models to estimate the gas flow in a two-phase mixture being pumped through an ESP. Using these models and experimental system response data, the pump operating point can be controlled. The models are based on nonparametric identification using a support vector machine learning algorithm. The learning machine’s hidden parameters are determined with a genetic algorithm. The results obtained with each model are validated and compared in terms of estimation error. The models are able to successfully identify the gas flow in the liquid-gas mixture transported by an ESP.

scholarly journals Flow Assurance in Subsea Pipeline Design for Transportation of Petroleum Products

2017 ◽  
Vol 07 (02) ◽  
pp. 311-323
Author(s):  
Son Tung Pham ◽  
Minh Huy Truong ◽  
Ba Tuan Pham
Keyword(s):  
Petroleum Products ◽  
Flow Assurance ◽  
Subsea Pipeline ◽  
Pipeline Design
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