Abstract

To support the complex operation of a large gas transmission system, information must move rapidly and accurately within NOVA and between NOVA and its business partners. With the implementation and integration of systems to perform pipeline control (SCADA), commodity management, electronic flow measurement (EFM), and electronic data interchange (EDI), this goal is being achieved.

This paper will follow a typical process from a customer's electronic request for gas, through the commodity management system for contractual and operational checks, to the issue of a change in flow, the control and measurement of that flow through the SCADA and EFM components, back through the commodity management system, and through to the communication of the transported commodity totals back to the customer.

Introduction

NOVA Corporation of Alberta is a widely held company operating internationally from headquarters in Calgary, Alberta, Canada. NOVA adds value to energy through producing, marketing and transporting natural gas and upgrading natural gas and other hydrocarbons into chemicals and plastics.

NOVA's Alberta Gas Transmission Division (AGTD) is responsible for receiving, measuring, quality control, and transmission of Alberta natural gas within and exported from the province. This responsibility includes the planning, design, construction and operation of NOVA's natural gas transmission facilities in Alberta.

As of December 31, 1992, the AGTD pipeline system consisted of 18,400 kilometres (11,433 miles) of pipeline, ranging in sizes from 51 mm to 1219 mm (2 to 48 inches); 825 receipt points and 149 major delivery points; and 44 compressor stations marshaling 1,040,900 horsepower of total compression.

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