Flow Assurance of Wet Gas Pipelines From a Corrosion Viewpoint

2002 ◽  
Author(s):  
Rolf Nyborg ◽  
Arne Dugstad
Keyword(s):  
Carbon Steel ◽  
Oil And Gas ◽  
Prediction Models ◽  
Process Equipment ◽  
Corrosion Control ◽  
Internal Corrosion ◽  
Application Range ◽  
Wet Gas ◽  
Offshore Oil And Gas ◽  
Stabilization Technique

In many offshore oil and gas projects under development, the pipeline costs are a considerable part of the investment and can become prohibitively high if the corrosivity of the fluid necessitates the use of corrosion resistant alloys instead of carbon steel. Development of more robust and reliable methods for internal corrosion control can increase the application range of carbon steel and therefore have a large economic impact. Corrosion control of carbon steel pipelines has traditionally often been managed by the use of corrosion inhibitors. The pH stabilization technique has been successfully used for corrosion control of several large wet gas condensate pipelines in the last few years. Precipitation of scale and salts in the pipeline and process equipment creates further challenges when formation water is produced. Different corrosion prediction models are used in the industry to assess the corrosivity of the transported fluid. An overview of the present models is given together with a link to fluid flow modeling.

scholarly journals Coatings & linings for oil & gas pipelines – the most effective method of corrosion protection for aged pipelines

2020 ◽  
Vol 305 ◽  
pp. 00016
Author(s):  
Ion Antonio Tache ◽  
Carmen Tache
Keyword(s):  
Corrosion Protection ◽  
Oil And Gas ◽  
Control Program ◽  
Corrosion Control ◽  
Gas Pipelines ◽  
Internal Corrosion ◽  
Below Ground ◽  
Infrastructure Failure ◽  
Water Gas

Pipelines around the world are in danger due to ageing, deposits and corrosion. Leaky fittings and cracks are an environmental hazard and cause the loss of valuable resources such as drinking water, gas, or oil. The pipelines may get corroded internally due to the nature of the fluid flowing inside and due to various other factors. The environmental and societal impact of infrastructure failure is a primary consideration for today’s pipeline operators. Without implementing safety measures and having a corrosion control program, corrosion makes transporting hazardous material unsafe. There are many methods NACE (National Association of Corrosion Engineers) recommends as part of a successful corrosion control program to protect oil and gas pipelines. Coatings and linings applied to pipelines whether above or below ground and often used in combination with cathodic protection. Different linings may be used for internal corrosion protection, provided the lining material does not degrade following long-term exposure to the transported fluid, at the pipeline pressure and temperature conditions.

A long history of wet gas pipelines in Victoria

2015 ◽  
Vol 55 (2) ◽  
pp. 415
Author(s):  
Steve Henzell
Keyword(s):  
Oil And Gas ◽  
Gas Pipelines ◽  
Gas Field ◽  
Initial Development ◽  
The North ◽  
Wet Gas ◽  
Industry Practice ◽  
Offshore Oil And Gas ◽  
The 1960S ◽  
Marginal Field

Australia's relative isolation and the harsh environment in Bass Strait have led to many innovations in offshore oil and gas developments. The initial developers were moving into frontier territory when Bass Strait was developed, with the harsh sea state and the water depths presenting major challenges. The original development of Bass Strait in the 1960s was tied to a wet gas pipeline philosophy, which was a novel step-out from normal industry practice. For example, the North Sea developments, which started shortly after Bass Strait, adopted dry gas export pipelines and required substantially larger platforms to process the gas for export. The cold waters of Bass Strait require an active hydrate management strategy and the success of hydrate inhibitors has been a key element in using wet gas pipelines. The initial development relied on methanol for hydrate inhibition, but this changed to a glycol-based hydrate inhibitor within 10 years of production start-up, due to challenges in the onshore production facilities. The use of mono-ethylene glycol for management of wet gas pipelines was demonstrated in Bass Strait. The success of the initial developments has given operators the confidence to pursue marginal field developments that rely on wet gas transport to the beach. The Minerva, Casino, Thylacine and Longtom gas field developments in Bass Strait have all adopted the same strategy, in part because of the confidence provided from operating the initial developments for many years.

scholarly journals An Investigation of Internal Corrosion of Oil and Gas Transporting Carbon Steel Pipes in the Niger Delta Area of Nigeria

2017 ◽  
Vol 2 (8) ◽  
pp. 22
Author(s):  
Obotowo W. Obot ◽  
Charles N. Anyakwo
Keyword(s):  
Carbon Steel ◽  
Niger Delta ◽  
Oil And Gas ◽  
Co2 Corrosion ◽  
Corrosion Monitoring ◽  
Temperature Oxidation ◽  
Internal Corrosion ◽  
Delta Area ◽  
Steel Pipes ◽  
Corrosion Mechanisms

Internal corrosion of carbon steel pipes of oil and gas Companies in the Niger Delta area of Nigeria using coupons and ER probes is presented. Corrosion mechanisms for the lines vary with the fluid type and operational parameters. Aqueous corrosion with, in some cases CO2 corrosion additive, erosion corrosion and elevated temperature oxidation are corrosion mechanisms implicated in the pipes. No H2S-induced corrosion was observed for all the lines investigated. They act separately or synergistically to exacerbate the corrosion attack.  Application of inhibitors of the amine group drastically lowered the corrosion rates. Effective inhibition regime had in an instance markedly lowered the corrosion rate of a line from 42.7080mpy to 1.3447mpy. The ER probes incorporation offered a comparative corrosion monitoring alternative and provided insight into the real time conditions of the lines over prolonged periods of times. The exercise proved very useful in determining the corrosion status of the pipes and helped to determine the lines that should require immediate maintenance intervention to obviate possible ugly incidents of breakouts and ruptures.

OCTOPLUS: A New Generation of FPSO for Deepwater

2006 ◽  
Author(s):  
Guillaume Geoffroy ◽  
Franc¸ois Pe´trie´ ◽  
Michel Vache´ ◽  
Karl Mitchell ◽  
C. Guedes Soares ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Process Equipment ◽  
Execution Plan ◽  
Oil Storage ◽  
Deep Waters ◽  
Gas Standards ◽  
Offshore Oil And Gas ◽  
The Cost ◽  
New Generation ◽  
Offshore Oil

Today, FPSOs are usually converted tankers (VLCCs) or box-shaped new-built vessels. In either case, the hull provides oil storage capacity whereas process equipment, utilities and accommodation are spread over the deck area. The hull is built or converted following conventional shipyard practices before the topside are installed as small pre-assembled units built to offshore oil and gas standards. The OCTOPLUS is a new concept Floating Production Storage and Offloading (FPSO) vessel designed for deep and ultra-deep waters. This new generation FPSO vessel allows the hull and the topsides to be built and transported independently, and then mated at the field location. To provide confidence in the concept to potential end users, the integrity of the OCTOPLUS design has been evaluated over a three year EC development study, which included model testing. The cost, schedule, execution plan and operation of a development based on the OCTOPLUS were also established and compared to a standard FPSO. This paper presents the results and conclusions of this three year study and the current development status of the OCTOPLUS concept.

Effect of Reeling Simulation on the Mechanical Properties of New Duplex Stainless Steel for Line Pipe

2014 ◽  
Author(s):  
Hidenori Shitamoto ◽  
Masayuki Sagara ◽  
Hisashi Amaya ◽  
Nobuyuki Hisamune ◽  
Daisuke Motoya ◽  
...  
Keyword(s):  
Mechanical Properties ◽  
Oil And Gas ◽  
Flow Line ◽  
Small Scale ◽  
Line Pipe ◽  
Stress Cracking ◽  
Wet Gas ◽  
Before And After ◽  
Sulfide Stress ◽  
Offshore Oil And Gas

Corrosion resistant alloys (CRAs) such as martensitic and duplex stainless steels (DSS) are used as a flow line material in corrosive wet gas environments (i.e., carbon dioxide and hydrogen sulfide environments). A new DSS which consists of 25mass%Cr - 5mass%Ni - 1mass%Mo - 2.5mass%Cu has been developed for line pipe usage in slightly sour environments. There are several methods currently being used to install offshore oil and gas pipelines. The reel-lay process is fast and one of the most effective offshore pipeline installation methods for seamless, ERW, and UOE line pipes with outside diameters of 18 inches or less. In the case of the reel-laying method, line pipes are subjected to plastic deformation multiplication during reel-laying. Thus, it is important to understand the change of the mechanical properties of line pipes before and after reel-laying. In this study, full-scale reeling (FSR) simulations and small-scale reeling (SSR) simulations were performed to investigate the effect of cyclic deformation on the mechanical properties of the new DSS for line pipe. Furthermore, investigation of the most susceptible temperature range to cracking and sulfide stress cracking (SSC) tests were performed in slightly sour conditions.

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