Pipeliner's Resource Library

API 1160: provides a process within a management system framework for operators to assess potential risks and make day-to-day decisions. Through effective integrity management, pipeline operators can significantly reduce the likelihood of an incident and adverse effects on the public, employees, and the environment.

API 1173: established the framework for operators to implement Pipeline Safety Management Systems (SMS). A significant part of this recommended practice is a training and competency aspect.

API 1174: provides to operators of onshore hazardous liquid pipelines a framework that promotes the continual improvement of emergency planning and response processes, including identification and mitigation of associated risks and implementation of changes from lessons learned. This Recommended Practice assists the operator in preparing for a safe, timely, and effective response to a pipeline emergency.

API 1175: a recommended practice published by the American Petroleum Institute addressing how pipeline operators should maintain their leak detection program. The goal of the standard is to have the best leak detection system possible by always looking for continuous improvements to the individual LDS components achieving operational buy-in with the culture, strategies, KPIs, and testing.

API 1177: provides a framework for a quality management system (QMS) for onshore pipeline construction.

Chromatograph (Portable GC): an analytical device that combines the features of gas chromatography and mass spectrometry to identify different hydrocarbons within a test sample.

Compressor: helps facilitate the transport of natural gas from Point A to Point B by compressing the gas as it travels through the pipeline.

Compressor Station: the location where natural gas is compressed to increase its pressure, causing the gas to move through a pipeline. A compressor automation or optimization project addresses the needs of pipeline operators to improve reliability, response time, and data collection in the field.

Computational Pipeline Modeling (CPM): a digital method of mapping out a pipeline’s operational conditions and processes to track the flow of a liquid or gas through the pipeline.

Custody Transfer: the physical transfer of natural gas or liquid between operators. Accuracy is vital to ensure the safe and compliant transfer of a substance.

Custody Transfer Measurement: involves a metering point (location) where fluid is being measured for sale from one party to another. During custody transfer, accuracy is important to both the company delivering the material and the eventual recipient.

Distribution Pipelines: complete the process of delivering the substance to the desired destination. A Local Distribution Company (LDC) transports natural gas from a main delivery point to consumers through a pipe distribution system.

Electronic Flow Meter (EFM): measures the amount of substance flowing in a pipeline and performs other calculations that are communicated back to the system.

Electronic Gas Measurement: the process of measuring the quality of gas using a flow computer. Volumes are recorded and generated at field level, then imported into a measurement system.

Field Devices: the pipeline instrumentation located in the field that is used to gather data to send back to the operation or take action when certain requirements are met.

Flow Computer: averages and records all digital signals received from various types of flow meters, as well as analog or digital signals from temperature, pressure, and density transmitters.

Flow Monitoring: an analysis tool that provides a detailed view of the data to and from machines. When flow monitoring is enabled, its output defines which machines are exchanging data and over which application.

Gathering Pipelines: form a network of interconnected pipelines to gather a substance such as crude oil or natural gas to send to a treatment or processing facility.

High-Consequence Areas (HCAs): defined by PHMSA as a potential impact zone that contains 20 or more structures intended for human occupancy or an identified site. PHMSA identifies how pipeline operators must identify, prioritize, assess, evaluate, repair, and validate the integrity of gas transmission pipelines that could, in the event of a leak or failure, affect HCAs.

• MCA (Moderate-Consequence Areas or Medium-Consequence Areas): designated areas for gas transmission pipelines.

Industrial Internet of Things (IIoT): the use of connected devices for industrial purposes, such as communication between network devices in the field and a pipeline system.

LACT (Lease Automatic Custody Transfer) Unit: measures the net volume and quality of liquid hydrocarbons. The related system provides for the automatic measurement, sampling, and transfer of oil from the lease location into a pipeline.

Main Terminal Units (MTUs): used in a SCADA system to operate the Remote Terminal Units (RTUs) and transmit their data back to the facility.

Measurement Analytics: ensures that measurement data is correct and complete for consumption by downstream accounting services and for the end customers’ reports.

Measurement Data Management System: aggregates data, normalizes the data, and stores the data on a server database. This prepares the data for downstream processing.

Mega Rule: a set of new pipeline safety standards issued by PHMSA in October 2019 that brings 500,000 miles of pipeline under federal jurisdiction to ensure the safe transport of gas product.

Meter Proving: a method of physically testing the accuracy of a meter through the proving process of measuring temperature, pressure, flow rate, and density against a known prover.

• PD meter (Positive Displacement meter): requires fluid to mechanically displace components in the meter in order to measure flow.
• Turbine Meter: uses the mechanical energy of a fluid to rotate a “pinwheel” (rotor) in the flow stream to measure flow.
• Ultrasonic Meter: measures the velocity of a fluid using ultrasound technology to calculate volume flow.
• Coriolis Meter: measures the mass flow of liquid and natural gas as opposed to just volumetric flow.

Pipeline Safety Management Systems (PSMS): an industry-wide focus to improve pipeline safety, driving toward zero incidents.

Point to Point Verification (P2P): confirms that input or output from each field instrument is accurately and reliably reflected in the SCADA information presented to the controller.

Polling Rates: refer to the rate at which a station, unit, or communication device reports its location from the field.

Programmable Logic Controller (PLCs): a computerized system in operations that automates processes that require reliability within a given time period. PLCs are especially useful for pipeliners to automate difficult tasks in the field.

Pump: used in pumping stations to continue moving a substance through the pipeline.

Pumping Station: placed at strategic locations throughout a pipeline to check the pressure, continue moving the substance through the line, monitor the flow of the substance, and communicate the information to a facility.

Remote Telemetry Units (RTUs): electronic devices placed in the field. RTUs enable remote automation by communicating data back to the facility and taking specific action after receiving input from the facility.

• EFM Flow Computer: a type of RTU that measures the flow of gas or fluid and reports the data back to the facility. It differs from an RTU in that it is designed to compute flow using standard flow equations with specific timing and reporting requirements.

SCADA: a system of software and technology that allows pipeliners to control processes locally or at remote location. SCADA breaks down into two key functions: supervisory control and data acquisition. Included is managing the field, communication, and control room technology components that send and receive valuable data, allowing users to respond to the data.

SCADA Communication: there are several types of communication methods that can be used in a SCADA system to transmit data.

• Satellite Communication: includes a natural delay from the time a data request is made and the time the data is sent.
• Poll Response: only sends data if requested by the host. This creates limitations because you may need to wait up to 15 minutes for the full data package to be received.
• Report by Exception: sends data to the host when there is a change to the data.
• MQTT (Message Queuing Telemetry Transport): a publish-subscribe protocol that allows data to move quickly and does not bog down the system with unnecessary requests.

Telemetry: an automated communications process. During this process, measurements and other data are collected at remote locations and transmitted to receiving equipment for monitoring and data analysis.

Transmission Pipelines: consist of a long series of pipes that move substances across large areas. Compressor stations and pump stations are placed along the pipeline to continue moving the substance through the line.