Modeling erosion and sediment control practices with RUSLE 2.0: a management approach for natural gas well sites in Denton County, TX, USA

TransCanada Pipelines Ltd. (TransCanada) operates approximately 37,000 km of natural gas gathering and transmission pipelines. Within the Alberta portion of this system there are almost 1100 locations where the pipeline(s) traverse slopes, primarily as the line approaches and exits stream crossings. In the past, the approach to managing the impact of slope movements on pipeline integrity has been reactive; site investigations and/or monitoring programs would only be initiated once the slope movements were sufficiently large so as to easily observe cracking or scarp development. In some cases these movements could lead to a pipeline rupture. To move to a proactive hazard management approach and to optimize the maintenance expenditure, TransCanada has developed a new slope assessment methodology. The objective of this methodology is to establish a risk-ranked list of slopes upon which maintenance decisions can be based. Using only internal and public information on site conditions as input to predictive models for rainfall-ground movement and pipe-soil interaction, a probability of pipeline failure can be generated for each slope. Estimates of risk using a consequence-matrix approach enabled the compilation of a risk-ranked list of hazardous slopes. This paper describes this methodology, and its implementation at TransCanada, and presents some of the results.

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Numerical Investigation on Multiphase Erosion-Corrosion Problem of Steel of Apparatus at a Well Outlet in Natural Gas Production

Journal of Fluids Engineering ◽

10.1115/1.4040445 ◽

2018 ◽

Vol 140 (12) ◽

Author(s):

Zhang Jianwen ◽

Jiang Aiguo ◽

Xin Yanan ◽

He Jianyun

Keyword(s):

Fluid Flow ◽

Natural Gas ◽

Production Rate ◽

Gas Production ◽

Two Phase ◽

Gas Well ◽

Chemical Corrosion ◽

High Production Rate ◽

Erosion Corrosion ◽

Corrosion Problem

The erosion-corrosion problem of gas well pipeline under gas–liquid two-phase fluid flow is crucial for the natural gas well production, where multiphase transport phenomena expose great influences on the feature of erosion-corrosion. A Eulerian–Eulerian two-fluid flow model is applied to deal with the three-dimensional gas–liquid two-phase erosion-corrosion problem and the chemical corrosion effects of the liquid droplets dissolved with CO2 on the wall are taken into consideration. The amount of erosion and chemical corrosion is predicted. The erosion-corrosion feature at different parts including expansion, contraction, step, screw sections, and bends along the well pipeline is numerically studied in detail. For dilute droplet flow, the interaction between flexible water droplets and pipeline walls under different operations is treated by different correlations according to the liquid droplet Reynolds numbers. An erosion-corrosion model is set up to address the local corrosion and erosion induced by the droplets impinging on the pipe surfaces. Three typical cases are studied and the mechanism of erosion-corrosion for different positions is investigated. It is explored by the numerical simulation that the erosion-corrosion changes with the practical production conditions: Under lower production rate, chemical corrosion is the main cause for erosion-corrosion; under higher production rate, erosion predominates greatly; and under very high production rate, erosion becomes the main cause. It is clarified that the parts including connection site of oil pipe, oil pipe set, and valve are the places where erosion-corrosion origins and becomes serious. The failure mechanism is explored and good comparison with field measurement is achieved.

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(natural) gas well(bore)

Dictionary Geotechnical Engineering/Wörterbuch GeoTechnik ◽

10.1007/978-3-642-41714-6_140176 ◽

2014 ◽

pp. 901-921

Keyword(s):

Natural Gas ◽

Well Bore ◽

Gas Well

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Mobile sampling of methane emissions from natural gas well pads in California

Atmospheric Environment ◽

10.1016/j.atmosenv.2020.117930 ◽

2021 ◽

Vol 244 ◽

pp. 117930 ◽

Cited By ~ 1

Author(s):

Xiaochi Zhou ◽

Seungju Yoon ◽

Steve Mara ◽

Matthias Falk ◽

Toshihiro Kuwayama ◽

...

Keyword(s):

Natural Gas ◽

Methane Emissions ◽

Gas Well

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Effects of shallow natural gas well structures and associated roads on grassland songbird reproductive success in Alberta, Canada

PLoS ONE ◽

10.1371/journal.pone.0174243 ◽

2017 ◽

Vol 12 (3) ◽

pp. e0174243 ◽

Cited By ~ 4

Author(s):

Jenny Yoo ◽

Nicola Koper

Keyword(s):

Reproductive Success ◽

Natural Gas ◽

Gas Well

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Modeling Erosion and Sediment Control Practices: A Management Approach for Disturbed Sites

World Environmental and Water Resources Congress 2007 ◽

10.1061/40927(243)45 ◽

2007 ◽

Author(s):

D. J. Wachal ◽

K. E. Banks

Keyword(s):

Management Approach ◽

Sediment Control

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A CASE STUDY OF A CARBON DIOXIDE WELL TEST

The APPEA Journal ◽

10.1071/aj06015 ◽

2007 ◽

Vol 47 (1) ◽

pp. 239

Author(s):

J.Q. Xu ◽

G. Weir ◽

L. Paterson ◽

I. Black ◽

S. Sharma

Keyword(s):

Carbon Dioxide ◽

Natural Gas ◽

Large Scale ◽

Surface Flow ◽

Phase Changes ◽

Co2 Production ◽

Research Centre ◽

Well Test ◽

Cooperative Research ◽

Gas Well

This paper reports on the planning, procedure, results and analysis of a carbon dioxide (CO2) well test performed on Buttress–1, a well located in the Otway Basin, Victoria, Australia. A large-scale pilot study of CO2 sequestration is planned by the Australian Cooperative Research Centre for Greenhouse Gas Technologies (CO2CRC) in this area, which will involve, inter alia, taking CO2 from the Buttress reservoir and injecting it into a nearby depleted gas field. Understanding the production characteristics of this well is important to the success of this pilot, which forms part of a more extensive study to establish viable means to mitigate CO2 emissions to the atmosphere. This general backdrop forms the motivation for this study.Testing comprised of a standard suite of draw-downs and build-ups to determine reservoir/well characteristics, such as the well deliverability, the non-Darcy skin coefficient and the average reservoir permeability and volume.Compared to the wealth of experience developed over many years in testing oil and gas wells, the collective experience in CO2 well testing is extremely limited. The distinguishing features between this test and those of a typical natural gas well test need to be emphasised. Although, in general, flow testing a CO2 well should be similar to testing a natural gas well, differences in the thermodynamic properties of CO2 affect the analysis of the well test considerably. In particular, the non-Darcy skin effect is more pronounced and the wellbore and surface flow can involve dramatic phase changes, such as the formation of ice. Also, since CO2 is more compressible than a typical natural gas, the accurate measurement of the flow rate becomes more challenging. It is also apparent that the use of pseudo pressure, as opposed to simpler methods of dealing with the pressure dependency of key properties, is essential to the successful analysis of the pressure response to the CO2 production.

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