Evaluation of Wireless Tools for Determining Contact Status Between a Casing and the Carrier Pipe

2012 ◽  
Author(s):  
Fengmei Song ◽  
John McFarland ◽  
Xihua He
Keyword(s):  
Oil And Gas ◽  
Voltage Gradient ◽  
Property Damage ◽  
Steel Pipes ◽  
Close Interval ◽  
Ac Current ◽  
External Corrosion

For more than half a century, cased crossings have been used to support oil and gas steel pipes for crossing highways, railways, or rivers. Leaks or ruptures of cased crossings have occurred that resulted in casualties and property damage. Unlike uncased pipes buried in soils, which can be assessed for external corrosion directly and indirectly, the presence of a steel casing wall makes it challenging, even if possible, to conduct these assessments. The effect of the casing wall on the external corrosion of the carrier pipe inside the annulus is not well understood; it is unclear what tools can be used to effectively inspect the cased pipes. Empirical experience from the pipeline industry has shown that a few tools can be used to detect the contact status between a casing and the carrier pipe, which can help assess the severity of the carrier pipe external corrosion. Unfortunately, the criteria used to detect a contact status vary by user for the same tool and thus, the effectiveness of these criteria is uncertain. This paper reports results from a recent study aimed at evaluating the effectiveness of AC current attenuation, AC voltage gradient, and close interval (potential) survey as tools for detecting the contact status between a casing and the carrier pipe.

Reliability-Based Evaluation of Pipelines Using Above Ground Inspection Methods for External Corrosion

2004 ◽  
Author(s):  
Mark K. Fuglem ◽  
Mark J. Stephens
Keyword(s):  
Size Distribution ◽  
Special Consideration ◽  
Voltage Gradient ◽  
Direct Voltage ◽  
Close Interval ◽  
Ac Current ◽  
External Corrosion

Above ground inspection methods such as Close Interval, AC Current Attenuation, Direct Voltage Gradient and Pearson surveys are often employed to examine pipelines for external corrosion, especially when in-line inspection and hydrotesting are not feasible. Compared to in-line inspection, these methods can be superior in identifying general areas of corrosion, however, they generally have a higher probability of missing significant defects. This paper examines the use of quantitative reliability-based methods for assessing the integrity of pipelines that have been inspected using above ground methods where these inspections are followed up by a selective excavation and defect sizing process. Special consideration is given to the inference of the size distribution of undetected defects when the number of detected defects is small.

Quantitative Evaluation of Indirect Inspection Reliability and Pipeline Reliability Based on Statistical Methods

2004 ◽  
Author(s):  
James N. Mihell ◽  
David Coleman ◽  
Ryan Sporns
Keyword(s):  
Statistical Analysis ◽  
Voltage Gradient ◽  
Direct Examination ◽  
Factors Affecting ◽  
Incidence Data ◽  
Natural Gas Pipeline ◽  
Close Interval ◽  
Order Of Magnitude ◽  
External Corrosion ◽  
The Impact

To support an External Corrosion Direct Assessment (ECDA), Indirect Inspections were performed on a 44 km section of NPS 6 extruded polyethylene coated natural gas pipeline. Based on previous investigations of the pipeline, external corrosion defects were known to have occurred at coating holidays. Such holidays can often be detected using current voltage gradient surveys and close interval surveys. Two successive ACVG surveys over the pipeline were preformed. In addition, Close Interval Survey data were considered in order to complete the Indirect Inspection dataset. Statistical analysis methods were developed and employed against the data generated from these surveys so that the following objectives could be met: 1. Assess the reliability of the Indirect Inspection technique in terms of its ability to locate coating holidays and hence, its ability to locate potential corrosion features; and, 2. Assess, in quantitative terms, the reliability of the pipeline in terms of its potential for failure, and quantitatively establish the impact that the Indirect Inspection and dig program had in improving that reliability. In completing the first objective, duplicate survey results were compared with Direct Examination results. The statistical analysis provided a means of estimating technique reliability, which was conservatively estimated at 96%. Subsequent evaluation of factors affecting technique reliability indicated that the density of indications and consistency of applying the Indirect Inspection technique had a bearing on the overall reliability. The second objective was completed by applying the results of the Indirect Inspection reliability study to a statistical analysis of corrosion incidence data and corrosion size distributions that were derived from the Direct Examination data. Pipeline reliability was quantitatively expressed as a function of year of operation and the reliability of the Indirect Inspection technique. For the case examined, the Indirect Inspection techniques that were applied were found to increase pipeline reliability by approximately an order of magnitude.

Chromate and Molybdate Inhibitors Effects on Corrosion Charateristic of API 5L Grade B in a Brine Water Solution Containing 8 % NaCl

2021 ◽  
Vol 892 ◽  
pp. 115-123
Author(s):  
Viktor Malau ◽  
Wisnu Hakiki
Keyword(s):  
Corrosion Resistance ◽  
Oil And Gas ◽  
Corrosion Potential ◽  
Water Solution ◽  
Sodium Molybdate ◽  
Corrosion Process ◽  
Sodium Chromate ◽  
Polarization Method ◽  
Steel Pipes ◽  
Piping Systems

Piping systems at gathering stations in the oil and gas industries often fail due to corrosion attacks from the brine water solution containing 8% NaCl that flows through the system. This solution is highly corrosive on the API 5L grade B steel pipes, thereby shortening its lifespan, with an increase in the frequency of pipe replacements. However, the corrosion resistance of API 5L grade B pipes can be improved by using chromate and molybdate inhibitors. Therefore, the objective of this research is to improve the corrosion resistance of the steel pipes using sodium chromate (Na2CrO4) and sodium molybdate (Na2MoO4) inhibitors with concentrations of 0.2, 0.4, 0.6, 0.8 and 1,0%. This research also aim to determine the optimum concentration of inhibitors to produce minimum corrosion rate, by testing the brine water solution containing 8% NaCl through the potentiodynamic polarization method. The results show that generally, the addition of sodium chromate and sodium molybdate inhibitors to the brine solution causes the steel pipes to be more resistant to corrosion. Furthermore, the sodium chromate inhibitor concentration of 0.6% produces the greatest corrosion potential of – 400 mV with the lowest rate of 0.38 mpy, while sodium molybdate concentration of 0.4% produces the highest corrosion potential of – 385 mV with the lowest rate of 0.34 mpy. The results of SEM observations at 0.4% sodium molybdate concentration showed that the corrosion inhibition/passivation effect of the inhibitor made the steel surface smoother, while the sodium chromate inhibitor at similar percentage failed to reach the optimal concentration to inhibit the corrosion process.

scholarly journals Augmented Reality for Pipe Thread Connection Type Training

2021 ◽  
Vol 5 (1) ◽  
pp. 17-28
Author(s):  
Ravi Wiyantoko ◽  
Ahmad Hamim Thohari ◽  
Muhammad Dzuhri Maarief
Keyword(s):  
Augmented Reality ◽  
Oil And Gas ◽  
3D Visualization ◽  
Ground Level ◽  
Application Development ◽  
Thread Connection ◽  
Steel Pipes ◽  
Multimedia Development ◽  
Pipe Joints ◽  
Connection Type

The process of extracting oil and gas is carried out by drilling with a depth of more than 200 meters below the surface of the ground, so one steel pipe is needed to run the process. The manufacture of steel pipes for the opening process has special standards, one of which is a long pipe. To reach a depth of 200 meters below the ground level, a pipe connection is needed to reach that height. The method of connecting the pipes is called the Thread Connection Type. This method has more than 20 types of threads to be applied in pipe joints. To facilitate the discussion of the types of threads and their specifications, we need a technology that can be used interactive and mobile learning media to deliver detailed information on the type of thread. The author uses the use of Augmented Reality (AR) technology to be applied as an Android-based training media that can facilitate the existing Connection Thread along with special specifications with 3D visualization. This study aims to measure the validity and practicality of using ISO 25010 (in terms of functional suitability, performance efficiency, portability and usability) of learning media so that it is easier to understand and practical. The study consisted of two parts: 1) Validity by experts (5 experts), 2) Practicality by trainees or employees (16 participants) using the USE Questionnaire instrument. Furthermore, in application development using the Multimedia Development Life Cycle (MDLC) method as its development method. As a result, the application was declared feasible with the results of the percentage of experts Validity of 96% and Practicality by employees of 79%.

scholarly journals External Corrosion Detection of Oil Pipelines Using Fiber Optics

Sensors ◽  
2020 ◽  
Vol 20 (3) ◽  
pp. 684 ◽  
Author(s):  
Nader Vahdati ◽  
Xueting Wang ◽  
Oleg Shiryayev ◽  
Paul Rostron ◽  
Fook Fah Yap
Keyword(s):  
Fiber Optics ◽  
Optical Fibers ◽  
Oil And Gas ◽  
Metal Plate ◽  
Pipeline System ◽  
Corrosion Detection ◽  
Dog Bone ◽  
Fbg Sensors ◽  
External Corrosion ◽  
Plastic Parts

Oil flowlines, the first “pipeline” system connected to the wellhead, are pipelines that are 5 to 30.5 cm (two to twelve inches) in diameter, most susceptible to corrosion, and very difficult to inspect. Herein, an external corrosion detection sensor for oil and gas pipelines, consisting of a semicircular plastic strip, a flat dog-bone-shaped sacrificial metal plate made out of the same pipeline material, and an optical fiber with Fiber Bragg Grating (FBG) sensors, is described. In the actual application, multiple FBG optical fibers are attached to an oil and gas pipeline using straps or strips or very large hose clamps, and, every few meters, our proposed corrosion detection sensor will be glued to the FBG sensors. When the plastic parts are attached to the sacrificial metals, the plastic parts will be deformed and stressed; thus, placing the FBG sensors in tension. When corrosion is severe at any given pipeline location, the sacrificial metal at that location will corrode till failure and the tension strain is relieved at that FBG Sensor location, and therefore, a signal is detected at the interrogator. Herein, the external corrosion detection sensor and its design equations are described, and experimental results, verifying our theory, are presented.

Pressure capacity of sandwich pipe with cement-based core configuration under deep-water external pressure

2020 ◽  
Vol 22 (4) ◽  
pp. 1292-1326
Author(s):  
Feng Wan ◽  
Feng Guan ◽  
Chuanxi Zhou ◽  
Shaohu Liu ◽  
Ting Yang
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Core Layer ◽  
External Pressure ◽  
Fiber Reinforced ◽  
Shear Strength Test ◽  
Steel Pipes ◽  
Wide Range ◽  
Parametric Studies ◽  
Value Decomposition

Sandwich pipe, consisting of two steel tubes and a polymeric or cement-based material core layer, has been considered as an attractive solution for oil and gas transporting in deep water. In this paper, the characteristic responses and pressure capacity of sandwich pipes having fiber-reinforced cementitious composites core configuration under external hydrostatic pressure were investigated. The interface adhesion behavior between the fiber-reinforced cementitious composite core and the surrounding steel pipes was modeled based on the inter-layer shear strength test experiments conducted on the sandwich pipe specimens. The parametric studies were carried out to evaluate the influence of geometry parameters and steel grade on the buckling response and ultimate pressure capacity. Furthermore, 768 FE models of sandwich pipes covering a wide range of practical design configurations were rapidly constructed and analyzed using FE software package ABAQUS with the help of programming language Python. Finally, a simplified equation for predicting the pressure capacity of sandwich pipes within the scope of this study was proposed using dimensional analysis combined with singular value decomposition methodology.

Minimization of Residual Stresses in Submerged Arc Welding Process of Oil and Gas Steel Pipes by Committee Machine

2014 ◽  
Vol 564 ◽  
pp. 519-524
Author(s):  
Seyed Jafar Golestaneh ◽  
N. Ismail ◽  
M.K.A.M. Ariffin ◽  
S.H. Tang ◽  
Mohammad Reza Forouzan ◽  
...  
Keyword(s):  
Residual Stresses ◽  
Arc Welding ◽  
Oil And Gas ◽  
Traditional Approach ◽  
Welding Process ◽  
Submerged Arc Welding ◽  
Committee Machine ◽  
Steel Pipes ◽  
Input Variables ◽  
Submerged Arc

Submerged arc welding (SAW) is a well-known method to weld seam in manufacturing of large diameters steel pipes in oil and gas industry. The main subject of SAW design is selection of the optimum combination of input variables for achieving the desired output variables of weld. Input variables include voltage, amperage and speed of welding and output variables include residual stresses due to welding. On the other hand, main target in multi response optimization (MRO) problem is to find input variables values to achieve to desired output variables. Current study is a combination and modification of some works of authors in MRO and SAW subjects. This study utilizes an experiment design according to Taguchi arrays. Also a committee machine (CM) modeling the problem by CM using two approaches. The first CM consists eight experts with traditional approach in computation and second CM includes elite experts. Genetic algorithm was applied to find CM weights and desired responses. Results show that proposed approach in CM has a smaller root mean squire error (RMSE) than traditional approach. The validation of CM model is done by comparison of results with simulation of SAW process and residual stresses in a finite element environment. Finally, the results show few differences between the real case responses and the proposed algorithm responses.

Analysis of Ruptures and Trends on Major Canadian Pipeline Systems

2004 ◽  
Author(s):  
Franci Jeglic
Keyword(s):  
Oil And Gas ◽  
Safety Performance ◽  
Third Party ◽  
Regulatory Requirements ◽  
The Past ◽  
Safety Interventions ◽  
Order Of Magnitude ◽  
Regulatory Interventions ◽  
External Corrosion ◽  
High Vapour Pressure

The number of ruptures per year is one of the National Energy Board’s (the Board) measures of safety performance of the federally regulated oil and gas pipelines. This measure was examined and analyzed over twenty, ten, and five years with respect to the rupture causes, ignitions, fatalities, injuries, pipeline age, in-line inspections, and the Board’s safety interventions. There were forty-six ruptures over the twenty-year period, twenty-three over the ten-year period, and seven over the five-year period (Ref. 1 and 2) on the 43,000 km of the regulated pipelines. The average time from the pipeline installation to the time of rupture for the time-dependent rupture mechanisms is twenty-eight years. There were three fatalities and fourteen injuries caused by the ruptures of the federally regulated pipelines over the past twenty years. Ruptures associated with fires of the gas and high vapour pressure pipelines caused most of the fatalities and injuries. The dominant rupture causes are external corrosion, stress corrosion cracking, and third-party damage in this order of magnitude. The pipelines that ruptured during the last five years were internally inspected. The in-line inspection tools could not properly detect the defects that caused the ruptures. Regulatory interventions, such as public inquires, Board Orders, and regulatory requirements, have reduced the number of ruptures due to the targeted cause. The number of ruptures and safety consequences associated with them have decreased over the last ten years.

scholarly journals Effect of pH in SRB (ATCC 7757) Growth for Oil and Gas API X 70 Steel Pipes

2019 ◽  
Vol 3 (1) ◽  
pp. 30-36
Author(s):  
Zuraini Din ◽  
Keyword(s):  
Carbon Steel ◽  
Corrosion Rate ◽  
Oil And Gas ◽  
Desulfovibrio Desulfuricans ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Corrosion Failure ◽  
Bacteria Growth ◽  
Steel Pipes ◽  
Metal Pipes

In the oil and gas industry, pipeline is the major transportation medium to deliver the products. According to [1] containment of pipeline loss to indicate that corrosion has been found to be the most predominant cause for failures of buried metal pipes. MIC has been identified as one of the major causes of underground pipeline corrosion failure and Sulphate Reducing Bacteria (SRB) are the main reason causing MIC, by accelerating corrosion rate. The objectives of this study is to study the SRB growth, Desulfovibrio desulfuricans ATCC 7757 due to pH and determine the optimum value controlling the bacteria growth on the internal pipe of carbon steel grade API X70. The result shows that the optimum SRB growth is at range pH 5-5 to 6.5 and the exposure time of 7 to 14 days. At pH 6.5 the maximum corrosion rate is 1.056 mm/year. Corrosion phenomena on carbon steel in the study proven had influence by pH and time. From this result pitting corrosion strongly attack at carbon steel pipe. In the future project, it is recommended to study the effect of different pipe location for example the pipeline under seawater.

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