Lyntas/mining_domain_knowledge_reference_dataset huggingface dataset:
Area: Asset Integrity Management
This AMP highlights proposed expenditure resulting from necessary upgrades or improvements to the AGP (Amadeus Gas Pipeline) assets, with discussion on the merit of each. This document is a Technical Asset Management Plan and generally does not address commercial or administrative issues involved with the operation of the AGP. The AMP is written on the basis of the best known information at the time of writing.
Area: Asset Integrity Management
The AGP is reaching mid-life (approximately twenty seven years) where the updating and replacement of some components is necessary
Corrosion Under Sleeves
The pipeline has suffered corrosion under the joint coatings applied during construction. The damage is extensive and it is necessary to increase integrity measures with targeted inspection, excavation and repair.
Unpiggable Darwin City Gate to Channel Island Spurline
The Channel Island Spurline is currently unpiggable due to a step change in diameter of the pipeline at the Channel Island Bridge from 300 mm to 200 mm. it is imperative to ensure that this spurline is piggable to manage its ongoing integrity.
Coating Refurbishment of Below Ground Station Pipework
The original below ground station coating consists predominantly of coal tar enamel (CTE) and some tape wrap. The condition of the CTE coating is generally poor and a project has commenced to progressively replace the CTE with high build epoxy (HBE).
Area: Asset Integrity Management
AMP is a locally developed document and is reviewed annually to ensure that the content is current.
The AMP will form the basis for non-routine additions to the annual work program incorporating projects regarding longer term integrity management
This plan does not include routine operations detail or costs estimates associated with these tasks.
Area: Asset Integrity Management
Asset Management Process
The Pipeline Licences, AS 2885 and other mandatory or statutory standards and regulations form the basis of the compliance requirements.
Area: Asset Integrity Management
Relationship With Other Planning Documents
XXX has developed a Pipeline Management System (PMS) as required by AS 2885.3 -2012. The PMS provides guidance to the organisation regarding high pressure gas pipeline management and operation techniques. 
The PMS also specifies subservient documents including the Pipeline Integrity Management Plan (PIMP). The PIMP is a local document which is specific to particular assets or groups of assets. The PIMP carries relevant details of the assets and a detailed summary of the integrity challenges and mitigation. The mitigation identified in the PIMP drives the majority of funding provisions detailed within the AMP.
Area: Asset Integrity Management
Operating Constraints
The AGP is cXXXble of operating at is full Maximum Allowable Operating Pressure (MAOP) and has adequate cXXXcity to meet all delivery requirements.

Projects are delivered in two separate management frameworks dependant on their size and complexity.
Area: Asset Integrity Management
Major Projects are delivered using the project management framework, Project Portfolio Management (PPM) tool. The PPM tool is Microsoft Project Server 2010 and provides all project managers a uniform structure and platform for project scheduling, documentation, reporting and monitoring for every stage of the life of a project
Area: Asset Integrity Management
Generally most Minor projects for the AGP consist of SIB CAPEX and MEJ OPEX and are predominantly managed using NT XXX personnel. Generally most Major Projects for the AGP consists of growth CAPEX are managed by a dedicated project team within Infrastructure Development, with local NT input where required
Area: Asset Integrity Management
Coating
The pipeline is coated with yellow jacket polyethylene which has proven to be a suitable coating for the conditions. However, MLVs and scraper stations are suffering coating degradation and despite applied Cathodic Protection (CP) there is still a risk of corrosion. The original coating material was in many cases coal tar enamel (CTE) which has the potential to shield the CP current providing an unprotected environment where metal loss and stress corrosion cracking (SCC) may be active.
There are significant problems with corrosion under failed heat shrink sleeves used for field applied joint coatings during construction. This has led to extensive metal loss across the many field joint coatings. A program is in place to inspect and repair critical metal loss defects associated with heat shrink sleeves.

In Line Inspections 8.1.1.2
The Intelligent Pigging schedule for the AGP is recommended at ten year intervals to adequately monitor and manage the corrosion under the heat shrink sleeves, with the exception of the Mataranka to Helling section which has an interval of seven years due to the higher corrosion growth rates at heat shrink sleeves. The failure mode for these defects could be a rupture, albeit very much less likely than a leak due to the restricted critical defect length which is somewhat limited by axial length of the sleeves.
The Tennant Creek area is earthquake prone and gauge pigs are run in the event of a significant tremor. Significant damage could lead to the development of a rupture failure at a later date.

The 12 kilometre long DN300 DCG to CIMS section is currently not piggable due to 
 No scraper station facilities;  a section of DN200 pipe across the road bridge; and  tight radius bends on the bridge approach.
The preferred option is a HDD under the bridge. The other options include replacing the DN200 section under the bridge with DN300 pipe or having a midway scraper station that can receive DN300 pigs and launch DN200 pigs.
Area: Asset Integrity Management
Direct Current Voltage Gradient
Coating defects can be identified proactively by Direct Current Voltage Gradient (DCVG) which utilises the potential at the surface created by the coating defect. Alternatively, coating defects can be identified by intelligent pigging at corrosion sites.
For unpiggable pipelines the DCVG process is necessary to ensure that coating defects can be identified and repaired prior to corrosion of the underlying steel, creating a failure.
Area: Asset Integrity Management
Cathodic Protection
In 2004, a review of the CP system led to a two stage improvement process being implemented. 
In 2014, a new impressed current site was installed near Lake Woods (KP823) and the ground bed at Fergusson was refurbished. Due to continual degradation of the yellow jacket coating, continual upgrades to the CP system will be required.
Stage 2 works included an AC mitigation study of the AGP. This study indicated that AC mitigation is required from Townend Road to CIMS and also the length of the Katherine Lateral. The modelling of the effects of these power lines on the AGP is currently underway and required mitigation works are planned for FY16 (pending approval from PWC).
For the recent intelligent pigging inspections of DN300 sections, the GE Length Adaptive Pressure Analysis (LXXX) method was used to perform integrity assessments based on the intelligent pigging data.
Area: Asset Integrity Management
The 12 kilometre spurline runs from DCG to the CIMS with approximately 600 metres of DN200 pipe installed on the bridge crossing towards the end of the section.
This spurline is subject to the following integrity threats:
 External corrosion. The cathodic protection criteria is more stringent for this spurline at -950 mV to Cu/CuSO4 (compared to standard value of -850 mV) due to the possible presence of sulphur reducing bacteria (SRB) in the coastal soils. Intelligent pigging would allow the extent of corrosion, especially at disbonded heat shrink sleeves, to be quantified.
 AC corrosion due the vicinity of nearby high voltage power lines (refer also to AC Mitigation works referenced in Section 7.1.2). Intelligent pigging would most likely detect AC corrosion if it is present.
 Lightning damage. Significant lightning damage has been found on this spurline and lightning strikes on thinner walled sections have resulted in a loss of containment. Intelligent pigging successfully detects lightning strike defects on pipelines.

A DN350 tool needs around 200 kPa differential pressure to get the pig moving and then 100 kPa differential pressure to keep it moving
Area: Asset Integrity Management
Electrical and Instrumentation
The sites are generally in good order, however they are not fully compliant with the latest hazardous area legislation.
A hazardous area survey has been completed identifying opportunities for improvement. A risk based equipment upgrade approach will be adopted across all sites.
Lightning strikes on the assets particularly in the northern area are often the cause of equipment damage. RTU and communications equipment are held as spares/inventory. A lightning and earthing study will be performed to identify areas for improvement. Upgrades will be performed at stations in order to reduce the extent of equipment damage from lightning events
An allowance for site batteries and chargers has been made to enable replacement as they fail due to age. An allowance has been made for the replacement of RTUs due to technology upgrades and/or failure due to age. An allowance has been made to replace aged cathodic protection units (CPU).
Area: Asset Integrity Management
Mechanical
Mechanically the sites are sound; however the Limitorque actuators on the MLVs are obsolete. A phased replacement program is scheduled. The MLV actuator at Tennant Creek is obsolete and will be replaced.
Slops tanks are installed at Darwin City Gate, Pine Creek, Katherine and Tennant Creek to capture hydrocarbon liquids from the filter-separators. These slops tanks have some compliance issues that require rectification. An upgrade of the Darwin City Gate slops was performed in FY15.
Area: Asset Integrity Management
Scraper Stations
The original below ground station coating at scraper stations and MLVs consists predominantly of coal tar enamel (CTE) and some tape wrap. The condition of the CTE coating is generally poor and a project has commenced to progressively replace the CTE with high build epoxy (HBE).
Area: Asset Integrity Management
Metering and Quality
There are no current metering issues that are causing billing issues. A number of outlets use orifice meters utilising NX19 calculations which is not considered best practice.
Area: Pipeline Construction Project
Flowlines
Flowlines are used as part of a crude gathering system in production areas to move produced oil from individual wells to a central point in the field for treating and storage. Flowlines are generally small-diameter pipelines operating at relatively low pressure. Typical in the United States flowlines are between 2 and 4 inches in diameters. 
Flowlines typically operate at pressures below 100 psi.
Flowlines are normally made of steel, although various types of plastic have been used in a limited number of applications.
Area: Pipeline Construction Project
Crude Trunk Lines
Crude is moved from central storage facilities over long-distance trunk lines to refineries or other storage facilities. Crude trunk lines operate at higher pressures than flowlines and could vary in size from 6 inches in diameter to as large as 4 feet, as in the TAPS in Alaska.10
Area: Pipeline Construction Project
Product Pipelines
Pipelines carrying products that are liquid at ambient temperatures and pressures do not have to operate at excessive pressures in order to maintain the product in a liquid state. However, liquids that vaporize at ambient temperatures must be shipped at higher pressures. For instance, ethane pipelines can operate at pressures up to 1,440 psi. Product pipelines usually are 12 to 24 inches in diameter, but can be as large as 40 inches in the case of the Colonial Pipeline, which carries gasoline and distillate from the Gulf Coast to northeast markets.
Area: Pipeline Construction Project
Pumping Stations
The handling and injection of additives, such as for viscosity reduction, often occurs at pump stations.
Area: Pipeline Construction Project
Valve Manifolds
Valves are installed at strategic locations along the mainline pipe to control flows and pressures within the pipe and to isolate pipe segments in the event of upset or emergency conditions. Regardless of design, all valves require regular monitoring and maintenance.
Area: Pipeline Construction Project
Valves
Valves located in the mainline must be compatible with pigging equipment
Area: Pipeline Construction Project
Corrosion Control Systems
Corrosion control of pipeline systems primarily composed of steel and other metals is critical to system integrity. Buried metallic objects will corrode (chemically oxidize) through participation in electrochemical reactions if not adequately protected. Corrosion control is accomplished through a variety of means. In most instances, paints and protective coatings are applied followed by wrapping and taping sections of mainline pipe prior to burial to isolate the metallic pipe and prevent its participation in electrochemical reactions. In addition, cathodic protection is provided through the use of an impressed current or sacrificial anodes to counteract.
Area: Pipeline Construction Project
Catholic protection involves either the use of an 
Impressed current 
For impressed-current systems, anodes are buried in the soil proximate to the section of buried pipe being protected. A current is applied to the anodes equivalent to the current that would result from the electrochemical oxidation of the pipe. This current is allowed to flow through the soil to the pipe which then completes the circuit. This impressed current counterbalances the flow of electrons from the pipe to the soil that would otherwise have resulted from the pipes oxidation, thereby canceling that reaction. Impressed-current systems can be monitored from the ground as a demonstration of their continued proper performance. Unless malfunctions occur, impressed-current system components that are buried with the pipe will typically not need replacement for 20 to 25 years, and many last over the lifetime of the pipe.
SCADA systems can be configured to monitor the performance of impressed-current systems.
Alternatively, individuals using monitoring devices can check their performance (i.e., measure the voltage being applied to the pipe) at ground-level monitoring points installed along the length of the pipeline.
Area: Pipeline Construction Project
Catholic protection involves either the use of an Sacrificial (Galvanic) electrodes.
Composed of magnesium or zinc, both of which corrode more easily than the iron in the pipe, are electrically bonded to and buried alongside of the pipe. Current is allowed to naturally flow from the pipe to the ground; however, it is the zinc or magnesium in the electrodes that looses electrons in the process. Thus, the electrodes are sacrificed to protect the iron pipe. Galvanic electrodes must be replaced periodically. Site-specific conditions of soil moisture and electrical conductivity determine the proper anode replacement intervals.
Area: Pipeline Construction Project
General Pipeline Design Considerations
The major steps in pipeline system design involve establishment of critical pipeline performance objectives and critical engineering design parameters such as:
 Required throughput (volume per unit time for most petroleum products; pounds per unit time for petrochemical feedstocks); 
Origin and destination points;
Product properties such as viscosity and specific gravity;
Topography of pipeline route;
Maximum allowable operating pressure (MAOP); and
Hydraulic calculations to determine: Pipeline diameter, wall thickness, and required yield strengths; Number of, and distance between, pump stations; and Pump station horsepower required.14
Area: Pipeline Construction Project
Pipeline Coating
Protective wrappings, followed by the application of tape to the edges of the spirally applied overlapping wrapping, are often installed on the exterior of the pipe to further assist in corrosion control, but also to primarily protect the pipe from mechanical damage at installation. Wraps and tape often are impregnated with tar or other asphalt-based materials and heated in place once applied, to ensure uniform coverage.
Figure 2.1-1 illustrates installation of an exterior pipe tape wrap prior to the pipes installation in its trench. Other coatings, such as thin-film epoxy and extruded polymers are also used as alternative to wraps and asphaltic coatings.
Area: Pipeline Construction Project
Methods used to detect product leaks along a pipeline can be divided into two categories, 
Externally based (direct)
Externally based methods detect leaking product outside the pipeline, and include traditional procedures such as ROW inspection by line patrols, as well as technologies like hydrocarbon sensing via fibre optic or dielectric cables.

Internally based (inferential).
 Internally based methods, also known as computational pipeline monitoring, use instruments to monitor internal pipeline parameters (i.e., pressure, flow, temperature, etc.), which are inputs for inferring a product release by manual or electronic computation (API 1995a).
Area: Pipeline Construction Project
Overpressure Protection
A pipeline operator typically conducts a surge analysis to ensure that the surge pressure does not exceed 110% of the maximum operating pressure (MOP). The pressure-relief system must be designed and operated at or below the MOP except under surge conditions. In a blocked line, thermal expansion is a concern, especially if the line is above ground.
Area: Pipeline Construction Project
Pumps and Pumping Stations
Desired material throughput values as well as circumstantial factors along the pipeline route are considered in designing and locating pump stations. Desired operating pressures and grade changes dictate individual pump sizes and acceptable pressure drops (i.e., the minimum line pressure that can be tolerated) along the mainline; grade changes also dictate the placements of the pump stations.
Area: Pipeline Construction Project
Valve Spacing and Rapid Shutdown
The spacings of valves and other devices capable of isolating any given segment of a pipeline are driven by two principal concerns:
Maintaining the design operating conditions of the pipeline with respect to throughput and flexibility and (2) facilitate maintenance or repairs without undue disruption to pipeline operation and rapid shutdown of pipeline operations during upset or abnormal conditions
Valves designed to prevent the backward flow of product in the event of a pump failure (check valves) will also be installed in critical locations. Valves may also be required on either side of an exceptionally sensitive environmental area traversed by the pipeline. Finally, valves will be installed to facilitate the introduction and recovery of pigs for pipeline cleaning and monitoring.
Area: Pipeline Construction Project
Electrical Interference
The question of the impact of the colocation of metallic pipelines and high-voltage transmission lines can be framed by three broad concepts: 
(a) Influence
(b) Coupling
(c) Susceptibility
Other issues that add to the overall impact are identified and discussed below.
Influence can be thought of as the sum total of the magnetic induction and ground-return currents. Coupling can be thought of as the distance between the source of the magnetic induction (power line) and the objects being affected (pipelines). Susceptibility relates to the vulnerability of the induction element (i.e., the metallic pipeline) to induced and ground-return currents.
Colocation may mean that the pipelines are located on an electric utility ROW directly underneath the power lines, usually buried in earth. This is the worse case for the coupling of magnetic induction currents, since the separation between the power line and the pipeline is very small. Thus, the full effect of the magnetic induction from the power line into the pipeline takes place.
The actual installation of the pipeline includes these major steps:
1. Clearing the ROW as needed.
2. Ditching.
3. Stringing pipe joints along the ROW.
4. Welding the pipe joints together.
5. Applying a coating and wrapping the exterior of the pipe (except for the portions of the pipe at each end, which is sometimes coated before being delivered to the job site).
6. Lowering the pipeline into the ditch.
7. Backfilling the ditch.
8. Testing the line for leaks
9. Clean-up and drying the pipeline after testing to prepare it for operation.
10. Reclaiming impacted environmental areas.
Area: Pipeline Construction Project
Standard pipeline construction is composed of specific activities including survey and staking of the ROW; clearing and grading; trenching; pipe stringing, bending, welding, and lowering-in; backfilling; hydrostatic testing; and cleanup. In addition to standard pipeline construction methods, the pipeline construction contractor would use special construction.
Area: Pipeline Construction Project
Movement and Staging of Pipeline Components and Construction Equipment
Pipe segments are normally delivered from their point of manufacture by rail to a rail off-loading yard conveniently located to the construction ROW (see Figure 3.3-4). From there, pipe segments are loaded onto flatbed trucks and taken to a material laydown yard that is temporarily maintained in an area close to the construction site (see Figure 3.3-5). Numerous laydown yards may be constructed to support individual pipe construction spreads. A truck typically carries a maximum of 20 pipe segments at a time; however, this varies by pipeline diameter, wall thickness, weight, and pipe stacking method.
Area: Pipeline Construction Project
Clearing and Grading
The survey crew will carefully survey and stake the construction ROW to ensure that only the preapproved construction workspace is cleared. The clearing and grading crew leads the construction spread. This crew is responsible for removing trees, boulders, and debris from the construction ROW and preparing a level working surface for the heavy construction equipment that follows. Depending on existing soil conditions, this may require bringing in additional materials such as stone and sand to create a temporary work road adjacent to the pipeline.
The clearing and grading crew is also responsible for installation of silt fences along the edges of streams and wetlands as necessary to prevent erosion of disturbed soil. Trees inside the ROW are cut down, roots are excavated; and timber is stacked along the side of the ROW for later removal. Brush is commonly shredded or burned. The amount of clearing required varies widely. Sometimes only one pass down the ROW with a bulldozer is required.
In virtually all circumstances, topsoils and subsoils are separately stockpiled adjacent to the trench. In most instances, the subsoil can be used to backfill the trench once appropriate bedding materials have been placed at the bottom of the trench and the pipe has been installed.
Area: Pipeline Construction Project
Stringing Pipe Joints along the ROW
Normally, pipe segments are delivered to staging areas closest to the point along the mainline where they will be installed and then subsequently deployed along the ROW. This guarantees that each joint needs only to be moved over to the ditch when it is ready to be welded into the pipeline. Not only does this save cost and time, it also lessens the potential for damage to the pipe before installation. Figure 3.3-7 shows pipe segments being deployed along the ROW in preparation for welding and installation into the trench (not yet constructed in this photograph).
In some rugged locations, pipe segments must be staged on the ROW with helicopters
Area: Pipeline Construction Project
Pipe Bedding Material
Bedding material must be clean sand or soil and must not contain stones having a maximum dimension larger than 0.5 inch. Material must be placed to a minimum depth of 6 inches under the pipe and 6 inches over the top of the pipe.