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Monitoring of corrosion in process pipelines has always been of paramount importance in ensuring plant-asset integrity. Similarly, steam traps play an important role in ensuring steam quality and, thus, the integrity of critical assets in the plant. The complete paper discusses these two aspects of monitoring asset integrity--real-time corrosion monitoring and real-time steam-trap monitoring--as implemented by the operator. Corrosion coupons and electrical resistance probes are among the most-tried and -tested methods to monitor corrosion, but the authors detail shortcomings of these systems, focusing their efforts on the option of using nonintrusive ultrasonic sensors for corrosion monitoring.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- (2 more...)
ABSTRACT Effective and successful utilisation of materials for oil and gas production systems is the essential integral part of a strategy to provide safety and sustaining economy. In this context, selection and optimisation of appropriate materials which can tolerate production scenarios are the underpinning issues. This paper describes the approach taken to optimise materials for sweet and sour service duties focusing on environmental and hydrodynamic parameters bearing in mind whole life costing. Past successes in effective use of carbon and low alloy steels are included highlighting key enabling criteria allowing extended use of these alloys. The paper combines extensive existing data, field experience with options for laboratory assessment hence offering progressive means of corrosion design for materials optimisation in hydrocarbon production. INTRODUCTION The search for new sources of hydrocarbon has pushed the operational activities to harsher environments in deeper high pressure/high temperature wells and deep water. These have imposed increased challenges to the economy of project development and subsequent operations wherein facilities integrity and materials optimisation are becoming the overriding issues. In addition, the economic and operational necessities for multi-phase transportation through sub-sea completions, long infield flowlines together with CO2 sequestration have a tendency to increased risk of corrosion in which materials optimisation underpins success. Materials optimisation and the effective strategy to corrosion management, therefore, still remain key operational obstacles to successful hydrocarbon production, economy and safety. Corrosion has wide-ranging implications on the integrity of many materials used in the petroleum industry. Its impact can be viewed in terms of its effect on capital and operational expenditures (CAPEX and OPEX) and health, safety and the environment (HSE) [1,2]. In this paper an integrated strategy to materials optimisation is illustrated to enable safe and trouble free operations whilst maintaining economy.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (3 more...)
ABSTRACT ABSTRACT The corrosion resistance of martensitic stainless steel at a high CO2 and simulated acidizing condition was studied. Modified 13Cr steels and new 15Cr steel show good corrosion resistance at the very high CO2 environment of 160ยฐC and 50 MPa CO2. Martensitic stainless steels showed high corrosion rate in the live acid condition, but those corrosion rates were lower than 22Cr duplex stainless steel. No localized corrosion was observed in martensitic stainless steels, but selective dissolution was observed between austenite and ferrite in 22Cr duplex stainless steels. The corrosion rate of new 15Cr in the spent acid condition was the lowest in these steels. The martensitic stainless steels showed better corrosion resistance than 22Cr duplex stainless steel in the inhibitor containing conditions. New 15Cr showed good corrosion resistance in the high CO2 environment and acidizing condition. INTRODUCTION The field application of AISI 420 13% Cr steel pipe is widely used for Oil Country Tubular Goods (OCTG), because it has good corrosion resistance in the high carbon dioxide (CO2) and chloride environment . Additionally, some modified 13%Cr steels with high strength and superior corrosion resistance have been proposed . Those materials show good CO2 corrosion resistance at elevated temperature and high CO2 environment. They have been used in field applications. However, with the development of deep well, the 13%Cr steel pipes are susceptible to sulfide stress cracking (SSC) in the sour environment containing hydrogen sulfide (H2S) and less corrosion resistant at elevated temperatures. Furthermore, high strength OCTG has been required for the development of deep wells. Based on these facts, new 15Cr steel with high strength and superior corrosion resistance has been developed . Recently, application of CO2 injections increased and severe environment with very high CO2 has been developed for production of CO2. The corrosion reaction of martensitic stainless steels in such a high CO2 environment was not clarified yet. Additionally, acid treatment has been performed to increase the oil and/or gas production. In the low pH condition such as acidizing environment, no passivation film exists on the stainless steel surface and severe corrosion occurs in those conditions. The corrosion performance for new 15Cr such a low pH condition was not clarified either. This paper describes the corrosion test results of martensitic stainless steel pipes in the high CO2 condition and simulated acidizing (live acid and spent acid) condition. EXPERIMENTAL PROCEDURE Four kinds of commercial pipe including two types of modified 13Cr steel, new 15Cr steel, 22Cr duplex stainless steel were used in this study. The chemical composition of pipes is shown in Table 1. The modified 13Cr steel pipes were low C type containing Ni and Mo. The new 15Cr steel pipe contained Ni, Mo, Cu and its microstructure was martensite. They were quenched and tempered after being rolled to obtain the yield strength of 655MPa (95 ksi) grade for modified 13Cr steel pipes and 861MPa (125 ksi) for new 15Cr steel pipe. 861MPa (125 ksi) grade 22Cr duplex stainless steel was used as a comparison material.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Acidizing (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Abstract This paper discusses the important role of materials engineering in contributing to the successful development and operation of marginal fields in the offshore environment, with particular reference to recent Phillips Petroleum developments in the UK and Norwegian sectors of the North Sea. The applications of alternative materials, such as aluminium alloys and coatings, high alloy stainless steels and GRP (glass reinforced plastics) are discussed, highlighting the benefits and limitations as currently perceived in conclusion, the paper reviews some of the issues, both technical and economic which may impede future possible applications of these materials. Introduction The discussion of a materials selection philosophy should be viewed against current industry trends in design and fabrication for new field developments in the North Sea. These are typically for platforms with minimum manning levels, e.g. 15 - 50 personnel, or "not normally manned" (i.e. operated remotely from an existing platform and maintained by regular BUT restricted visits of maintenance crews) and subsea facilities. Another trend of significance is the approach to design engineering. Many of the oil companies have been reducing their own in-house engineering resources and relying increasingly on the use of engineering contractor companies. Therefore, the effective transfer of operating experience and feedback on materials performance to the design contractors is of greater importance and remains as an on-going industry challenge. It is also worth defining what is meant by a "marginal field development" in the context of this paper and some of the associated implications. Simply, it is an offshore development project with a marginal profitability (usually due to the smaller volumes of recoverable oil and gas reserves weighed against the capital investment required), with a relatively short life span, typically 10-20 years. In the North Sea, these developments very often rely upon being tied into nearby producing platforms or pipeline infrastructures, or use "temporary floating production facilities" rather than fixed steel or concrete structures. The approach to engineering design and construction of marginal field developments often implies the following:- * a short cycle time for design and construction. * a desire for the minimum capital expenditure. * the use of EPC (Engineer, Procure and Construct)contracts, often "fixed price". * for an EPC contractor, minimum risk in the design and construction phases. * for the operator, a design concept which achieves minimum operating expense levels, i.e. through a low manning level or unmanned design concept. It is evident that some of the above comments are potentially in conflict, unless a "life-cycle" approach to materials selection is undertaken. 2. EMBLA Embla was the first woman in the Norse creation mythology. The recently installed Embla (2/7D) platform also has a few "firsts" both for the Phillips Norway Group and for the North Sea. It is the first unmanned remotely controlled platform in the Ekofisk area and it is the first time oil and gas will be recovered from a North Sea reservoir, more than 4000 meters below sea level. Embla is a steel jacket platform similar to the rest of the 25 Greater Ekofisk platforms but apart from this, Embla is one of a kind. New technology and new philosophies have made ft possible to develop this deep and marginal reservoir in a profitable manner. An early decision was made that the platform should be unmanned and that the latest technology for remote operations would be employed. The materials selection had to be tailor-made to suit both the remote operations concept and the unusually severe corrosivity of the produced hydrocarbons. The size of the platform was kept to a minimum, with no processing facilities onboard. The multiphase oil and gas are transported through a five kilometer pipeline to the Eldfisk 2/7FTP platform. Embla also receives its electrical power supply from 2/7FTP through a subsea cable. Production commenced from July, 1993, with current production at 25,000 barrels oil per day from four wells.
- Europe > United Kingdom > North Sea (1.00)
- Europe > Netherlands > North Sea (1.00)
- Europe > Denmark > North Sea (1.00)
- Europe > Norway > North Sea > Central North Sea (0.34)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 211/28 > Hutton Field > Brent Group Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 211/27 > Hutton Field > Brent Group Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > South Viking Graben > Block 16/29a > Maureen Field (0.99)
- (2 more...)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (3 more...)
ABSTRACT For many years, frequent replacement of corroded pipelines was an unavoidable cost where aggressive soil conditions promoted extensive external corrosion. External corrosion of water distribution systems leads to two major problems for water utilities. The first problem is the failure of the distribution system pipes. The second is the contamination of water as the contaminants in soil are transported into the distribution system.1 To protect against external corrosion, a number of methods including coatings and cathodic protection were used.2-3 These methods can reduce the corrosion damage in potable water pipelines effectively, but there are additional costs for equipment installation. Moreover, corrosion problems still can occur on the system under certain conditions. Thus, it is desirable to develop new low-cost pipeline steel with high corrosion resistance. It is well known that weathering steel containing small amounts of alloying elements such as Cu, Cr, Ni, Si, and P has been widely used because of its excellent resistance to atmospheric corrosion. This is because of the development of an adherent, protective layer formed on the steel.4-8 Furthermore, an attempt to improve the corrosion resistance of weathering steel by alloying it with Co was successful in a recent study.9 It was found that Co formed a wide range of stable complex compounds with Fe. In our previous work,10 the Cr and Cu compounds promoted more or less protective rust layers on weathering steel in an aqueous condition, as they do with an atmospheric condition. Accordingly, it can be expected that alloy-
- Asia (0.47)
- North America > United States (0.29)
- Materials > Metals & Mining > Steel (1.00)
- Water & Waste Management > Water Management > Water Supplies & Services (0.88)
- Energy > Oil & Gas > Upstream (0.68)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)