ABSTRACT Oftentimes smaller transmission systems will be designed and built with only essential telemetry in mind. While deliveries are not monitored in real time on SCADA, monthly consumption data is recorded and available. While this amount of telemetry is sufficient to accurately and appropriately monitor the pipeline, it may not provide enough data to produce a hydraulically accurate simulation model. We set out to determine the feasibility of creating a Transient real time model of one such small transmission system where as much as 80% of the deliveries are not on SCADA. This ~75-mile-long system is mostly comprised of larger seasonal agricultural customers which can draw the system down and impact the few residential distribution systems that are on the mainline. The real time model can be used to analyze potential improvements and/or system expansion alternatives and their effect on pressure at the delivery border station. We combined the use of a hydraulic simulator, load prediction software, and data analysis to develop a methodology to simulate the transient behavior for these non-SCADA points. Where SCADA was not available, historical data from similar type customers was analyzed to produce profiles that could be applied. A Real Time Model (RTM) was built utilizing both actual SCADA data and simulated SCADA to accurately model the transmission system. This model demonstrates that despite a large gap in the available real-time SCADA data, where missing data could account for as much as 80% of the total load on the system, we can model the behavior of the system by calculating and accurately estimating flows and pressures. In addition, users can easily convert the RTM into a transient predictive model where further feasibility and system improvements can be analyzed.

Abstract Operator Training Systems (OTS) are traditionally used for training pipeline controllers in how to deal with normal and abnormal operating conditions, however OTS can serve to provide multiple uses in an Oil & Gas pipeline software environment. One of these is as a test platform for a Liquid Computational Pipeline Model Leak Detection System (CPM LDS). This paper demonstrates such a use and outlines the benefits of providing a testing environment that takes into consideration normal operating conditions (NOC) as well as abnormal operating conditions (AOC) and their impact on LDS performance. LDS performance maps can then be generated for most anticipated pipeline conditions. Details of hydraulic modeling, control system emulation, and SCADA telemetry simulation will be discussed as well as their impact on the fidelity of the OTS response and subsequent accuracy of LDS predicted performance. Review of the level of abnormal operating conditions and their implementation on the OTS will also be outlined and the resulting OTS behavior. Lastly, the determination of expected LDS performance for a range of normal and abnormal operating conditions will be summarized. Introduction and Background The use of offline methods to establish performance metrics for leak detection systems has been common in the pipeline simulation industry. Regardless of the leak detection method, the necessity to define the anticipated performance and validation of the design of the system is important. Several papers have addressed this topic. A previous study has used historical SCADA data provided to the LDS and analyse the response of the LDS with the use of statistical methods to superimpose leak events (1). In the absence of real pipeline data, as in the case of greenfield projects, the LDS vendor is left to wait until such data is available to be able to create an initial performance map for the LDS. Conditions of the pipeline that are not normally encountered are also problematic as the historical data would not exist. This pertains to failure modes not normally encountered or combined effects of transients and failure modes. To address this, we propose to use the OTS as a leak detection test bed. Approach The use of the operator training environment as a test bed for defining LDS performance is based on the assumption that the training environment provides a reliable platform that will allow for realistic recreation of pipeline operating conditions. Based on Schneider Electric's SimSuite Pipeline™ modeling tool the test bed used to illustrate this has several components of the real pipeline operating environment. These are the duplication of the SCADA system and its functionality, the duplication of the field response in terms of PLC/RTU algorithm and device switch gear response, and lastly the modeling of the pipeline hydraulics. All these components integrated together serve as the test bed that will provide a high level of fidelity to the real pipeline response as seen by a LDS in the production environment. The Figure 1 shows the functional architecture of these components.

ABSTRACT In parallel with the design and construction of the Keystone pipeline, TransCanada and Telvent developed a fully integrated simulation environment including a dynamic hydraulic model, production SCADA system, simulated programmable logic controllers (PLCs), online leak detection, and batch tracking. This system served to test and develop control logic, the SCADA database, SCADA applications, online leak detection, and operational procedures prior to putting the pipeline in to production. Not only did this system allow Keystone to meet its regulatory training requirements, but it was able to predict interactions between field and control center pressure control systems, identify vulnerable areas of the pipeline during scenarios, verify over pressure protection systems, and allowed for initial tuning of the leak detection system prior to line fill. INTRODUCTION Typically the development of SCADA systems, online applications, control systems, and dynamic pipeline simulations are done as separate or sequential exercises. For existing pipelines this is often a product of technological development over the life of the pipeline. For smaller pipelines or new branches on larger existing lines, it is often impractical to invest in line-specific simulation or training systems. The Keystone Pipeline provided the unique opportunity of developing a full scope training, analysis and testing system for a large-scale green field project including all of these dynamic online systems. Through the course of the project a number of unexpected advantages were gained through what has been termed "full scope simulation." The Keystone Pipeline is a 1,854 mile (2,984-kilometre) crude pipeline beginning in Hardisty, Alberta and delivering to markets at Wood River and Patoka, Illinois and in the future to Cushing, Oklahoma (See Figure 1). It utilizes approximately 537 miles (864 kilometers) of existing gas pipeline and is designed to initially carry 435,000 barrels per day, which will later be increased to a nominal capacity of 590,000 barrels per day. The original purpose of this full scope simulator was to train operators on the specific dynamics of the Keystone pipeline; however, the core advantage of the system lies in the ability to dynamically test "live systems" in an offline environment that is nearly indistinguishable from the real world. Great strides were made in pre-tuning and testing of online leak detection, batch tracking, pressure control, batch cutting, swing logic and terminal control. In addition, engineering and support staff gained hands on training and experience with "live" systems while assisting in the development of the training system. The end result is a higher preparedness for operators, shorter commissioning times for online systems, and an efficient start up process for the pipeline. In the end this translates to an operation that is safer, more efficient, and more cost effective.

ABSTRACT Assessing whether a pipeline's balancing requirements can be met is a key day-to-day business process for system operators within the Gas industry. It is essential to manage the system to minimize compressor usage, unnecessary interruption, efficiently use linepack and maximise the use of capacity of the system to ensure a safe and secure supply. This paper describes how Advantica developed an automated decision support tool (the Nomination Acceptance Process, NAP) to simulate whether the shippers' nominations can be supplied over the forthcoming 48 hrs using both the current and predicted load on the system. Where demands cannot be met the decision support tool carries out a number of iterative on-line predictive simulations and provides details of the necessary actions required to balance the system to the system operators (e.g. buy/sell or interrupt). The inputs required to successfully manage this process are described, including data sources such as SCADA, hourly nomination profile data from external databases and user inputs. The paper includes details of how SCADA alarms are used to keep the operator informed of progress, and how the system is designed with redundancy, allowing it to fail-over between multiple instances of this business critical application. INTRODUCTION Premier Transmission Limited (PTL) was acquired from the 50/50 joint venture owners, BG Group plc and Keyspan Energy Development Corporation, on 18 March 2005 by Northern Ireland Energy Holdings Ltd (NIEH). PTL is the owner of the majority of the Scotland to Northern Ireland natural gas transmission pipeline (SNIP), which comprises: Scotland - Approximately 90km 24" diameter high-pressure pipeline connected to the BGE (UK) South West Scotland pipeline at Twynholm. Sub-sea - Approximately 40km of 24" diameter high pressure pipeline. Northern Ireland - Approximately 3km 24" high-pressure pipeline; a pressure reduction/off-take station supplying Ballylumford Power Station and an interconnection with the Belfast Transmission system. Phoenix Gas owns the pipeline beyond Ballylumford. In 2004 Bord Gais completed the new 115 km "North West" pipeline connecting the SNIP pipeline to the Coolkeeragh power station in Derry. This pipeline resulted in an increase in contracted delivery pressure, and in flow rates along the SNIP pipeline. This reduced the margins on the SNIP pipeline and increased the likelihood of need for interventions. In order to validate the proposed operation of the pipeline and to consistently maximize the throughput on the pipeline, Advantica delivered an automated predictive capacity-modelling tool. This allows PTL to identify in advance their systems capacity, and identify balancing actions that may need to be taken. The design and creation of the bespoke NAP application formed part of a larger implementation for PTL covering pipeline simulation and leak detection software.

ABSTRACT The current regulation environment for pipeline companies has created or reinforced the requirements for operational training programs and quality assurance procedures. Pipeline operators in the USA are regulated by the standards defined by DOT and companies overseas are establishing their own standards, following and sometimes exceeding the regulations of USA. At installations like the OCP (Oleoducto de Crudos Pesados - Heavy Crude Oil Pipeline) in Ecuador, where the pipeline crosses high sensitivity areas, including the Amazon Jungle and the Andean mountains, the pipeline operators are subject to extreme pressure by environmental and government agencies to guarantee safe operation of the line. The particular situation of the OCP, being a brand new pipeline, made the implementation of a training program a very special and highly demanding project. The first steps were to define the professional profile of the operators, select the tools to train them and then evaluate their performance on a line that was just being built. The main objective of this paper is to present the process that was stablished at the OCP to implement the training application, to train and evaluate operator performance on a completely new installation and how they gained confidence in this application to become their daily assistance tool to double check operational procedures and new strategies to run their pipeline. The paper also describes the requirements of the system defined by OCP, the functionality available in the application, the implementation process, the training program and the current procedures related to the usage of this application. ABOUT OCP Oleoducto de Crudos Pesados (OCP) Ecuador S.A., a partnership between EnCana, Repsol-YPF, Occidental, Petrobras, Agip Oil and Perenco, constitutes a strategic asset for the present and future of the Ecuadorian oil export and the country itself. The OCP Pipeline transports heavy crude oil approximately 500 km from the Eastern Ecuador to the Pacific Coast of Ecuador near Esmeraldas (See Figure 1) exhibiting an extreme elevation variance, approximately 14,000 feet total variance (4,064 meters). The pipeline consists of 4 different diameters NPS 24, 32, 34, and 36 and 31 associated diameter wall thicknesses and it is designed to transport a blended heavy crude oil. The pipeline is designed to be capable of delivering 450,000 bpd of heated crude oil, at a minimum pipeline blend of 18 degrees API Gravity, on a sustained basis to Esmeraldas. The corresponding peak delivery capability is approximately 518,000 bpd. See Figure 2 for a pipeline schematic. PROJECT REQUIREMENTS AND BACKGROUND Background Before the start of operations and for approximately one year during construction, an extensive recruitment and training plan was conducted at the OCP. Priority on Ecuadorian labor was a requirement and the lack of Ecuadorian pipeline background (only SOTE pipeline, the national 30 year-old pipeline without a SCADA system) was an important limitation. Extensive training programs were established to cover the lack of experience of most of the recruited people.

ABSTRACT With the improvements in Automation Systems and Web Ser-vices, the Operator's / Dispatcher's Role has broadened. In addition to their historical duties, Operator's / Dispatcher's are now responsible for delivering validated real-time data to the Corporation in a timely manner. Therefore, it is necessary to look at the Operator's / Dispatcher's Organizational Position to see how it can be strengthened in a sustainable manner. As the Position becomes more complex and Operators / Dispatch-ers receive longer contiguous days away from their Post, the need for "refresher" Activities grows. This cultural change has increased the need for a more comprehensive refresher / train-ing environment. This paper discusses one approach to such a sustainable environment. Our approach is to create a Vendor Neutral Platform for Real-Time Data Integration that readily Adopts new Vendor Independent, Standards Based Component Functionality thereby decreasing the time to implement new functionality. Provides the Architecture to Ensure Testing of new Component Functionality within an exact duplicate of the Live System - be-fore that Functionality is installed in the Live Sys-tem Train, Certify, and re-Certify Pipeline Operations Personnel on a copy of the Live System - thereby ensuring proper operations. Afford a full duplicate of the actual Control Room that serves as the Secondary Control Center in an emergency, the Training Center, and the Software and Hardware Testing Center. Segregates Industrial Control Domain (ICD) Functional-ity from Manufacturing Execution System (MES) Func-tionality and provides the structure to continually en-hance both environments. These concepts have become practical due to the evolving In-formation Acrhitecture and the fact that many pipelines now have fiber running standard high speed Ethernet connecting the Pump Stations, Tank Farms, Custody Transfer Points, Block Valve Shelters, Cathodic Protection Shelters, etc. This paper presents these concepts in terms of a system archi-tecture for a testing environment that integrates three SCADA Vendors and three major real-time component Vendors. The environment supports the legacy SCADA Vendors while pro-viding the means for "Best of Breed" Functionality to be inte-grated into 1) a single Microsoft SharePoint Portal Environ-ment and 2) into the Industrial Control Domain (ICD). Simu-lation was performed by a simple simulator that received the signals from each of the SCADA Systems via OPC DA and delivered the responses via OPC DA as though the responses were from field devices. In practice, the Testing Environment can be used as a Secon-dary Control/Training/System Testing Center. A copy of all the components within the MES Environment can be con-nected via simulated XML Messages and within the ICD can be connected via OPC DA to a Pipeline Simulator of the de-sired fidelity. In the Main Control Center, the live version of those same ICD components would be connected to live equipment via other OPC DA Servers. The MES functionality should also be duplicated within the Testing Environment.

ABSTRACT Real time simulation tools for gas pipelines are already a reality in control central rooms, providing safer and more efficient operations, complementing SCADA functionalities for gas pipeline supervision and monitoring. This paper discusses the use of an integrated system to manage all phases between nominations and allocations, including planning dispatch and marketing. The same system is able to work as "leak detection" and also an online simulator that is integrated to SCADA system. The paper also discusses all phases of system implementation and configuration, real time compressor tuning issues, implementation of a real time model with focus on data integration, leak detection experience with gases and the use of the system to achieve compressor fuel optimization under transient conditions. This paper gives a breath description of the set of tools, named Advanced Functions used by TBG in Bolivia-Brazil Gas Pipeline Operation that includes: real time monitoring module; predictive module, used for operational strategies, planning for future operations And what if sceneries simulation; look ahead module, used to warn the operator for operational situations that might occur in the future; training simulator, used for operators training and qualification, among others, and the integration between SCADA, Advanced Functions and Commercial System that includes online nomination. All three systems are integrated and they exchange data between them continuously. INTRODUCTION This paper has the objective of describe the experience of TBG in the implementation and utilization of a set of tools, called Advanced Functions, in Bolivia-Brazil Pipeline, since the selection of the modules until the acceptance tests including all phases of configuration, installation, data exchange with SCADA and tuning. The benefits achieved with the use of these modules are also discussed, as well the aspects of integration between the tools. NOMENCLATURE PMS- Pipeline Monitoring System GMS - Gas Management System SCADA - Supervisory, Control and Data Acquisition Paper1. Advanced Functions The Advanced Functions for Bolivia Brazil Pipeline are a set of tools that allows reproducing, in real time the hydraulic behavior of the pipeline. The basic information is: – Pressure, flow, temperature, valves' status and equipment like compressors and regulators; – Detailed configuration of compressor stations, main line and others equipments such as valves; – Complete definition of the fluid with information like chromatography, viscosity and density. The modules implemented by TBG were: 1.1. Real time module : reproduces all operational conditions of the pipe, through the acquisition of SCADA data each 30 seconds; has all the system details configured, including compressor stations with compressor curves, fuel consumption and all valve information, including low pressure closing and line break configuration; 1.2. Line pack: presents the volume or mass, inside the line; 1.3. Composition tracking: determines the gas composition in every point of the line; it's possible to track both composition and calorific value; 1.4. Pig tracking: determines the position and speed of the pig inside the line, considering launch time, bypass and pressure differential through the line;

1.0 ABSTRACT As natural gas pipeline operations within North America become more competitive, most companies are looking for any advantage to reduce annual operating and maintenance expenses which will keep transportation tolls as low as possible. With the major advances in pipeline SCADA systems and significant improvements in desktop computing, Real Time Models (RTM's) have become a reality in the natural gas pipeline industry over the past decade. RTM's have typically been implemented on pipelines to take the place of physical field facilities that are required to provide pipeline pressure data where SCADA information has been too difficult to obtain or justify. This has been a common occurrence in recent years as new residential communities move in on existing pipeline rights of way. When new pipelines are constructed, the ability to integrate SCADA facilities is much easier since the additional costs can be absorbed into the larger overall project cost. Once a pipeline is utilizing and applying SCADA data, an RTM can be implemented and ultimately become a multi-functional tool for gas controllers and engineering support staff to operate and optimize the pipeline. One of the primary challenges for pipeline companies employing an RTM is endeavoring to keep the model current with system network modifications as well as changes in company personnel. Moreover, an RTM is quite often developed with no intention of being implemented as a mission critical system, which in turn can cause the greatest degeneration of the intended application. This lack of recognition inevitably results in disuse and disinterest. Without this importance given to the RTM a large majority of them realize the fate of ending up locked in a back room collecting dust. A typical response from a company employee asked if they still use their RTM is "the person who developed it transferred to a different department" or "the network is so far out of date". Realistically, when an RTM is operationally distinguished as a mission critical system and is integrally linked to a pipeline SCADA system, the results can be very rewarding for employees responsible for maximizing the optimal performance of the pipeline. This paper will recount the methodology of how Alliance Pipeline installed a mission critical RTM model and how it is currently being used nearly two years later. The model was designed to perform many tasks and calculations that most other pipelines would house within their SCADA systems. Alliance resolved that the RTM software was incomparable, with regard specifically to hydraulic calculations. Therefore, the RTM is treated and supported with a similar level of criticality, as is the pipeline SCADA system.

1 - Introduction One of the most significant issues for those who deal with math models and calculation tools is to "tune" the models to the actual operating conditions to the end of obtaining the best results. Obviously, in an existing network this "tuning" is carried out by comparing the measured variables and those obtained by making calculations under different operating conditions. As a matter of fact, in a pipeline system in operation different actions can be performed to check up the accuracy of the simulation model vs the system performance, e.g., run or stop compressor stations; put loops into or out operation; open or close block valves; etc. But all the above-mentioned maneuvers should be considered "standard conditions" and can be frequently performed in any pipeline network. Now then, the case we are focussing on in this paper is the analysis of a pipe rupture. Needless to say, this is a "non standard condition" and when this kind of incident takes place, it turns out to be an extraordinary and unique opportunity to compare simulation analysis results vs measured data. Therefore, the aim of this paper it to gain a better understanding of the model capabilities and accuracy to study this type of unusual phenomenon (non isothermical flow). In evaluating the rupture phenomenon and the gas mass flowing through a given pipe area, we might establish an analogy between the affected pipe area and the throat of an adiabatic nozzle, where the nozzle walls become parallel. 3 - Gas Network Description This case study is a 20-inch-wide and 650-mile-long pipeline that carries 85 MMSCFD of natural gas from Argentina to Chile, crossing the Andes mountain chain reaching a height of up to 15000 ft above sea level. On January 27, 2002, at 10:44 p.m. a rupture took place between the V2AR and V3AR valves on the Argentine side as shown above. Rupture data were measured by the SCADA system in V1AR,V3AR and V5AR. The objective of this paper is to compare these measured data with results obtained from a simulation analysis. Our mission will be to calculate the amount of gas lost as a result of the rupture, for which purpose we need to know the sequence of events reported that will be used as input data for the simulation. Also, we need to determine when V2AR was closed since there are no SCADA measurement available for that valve. 4 - Events Chronology With the exception of the rupture and the closure of V2AR, the rest of the above-cited actions were taken by the shift operators from the control room in Buenos Aires. As exhibited in the network scheme, the rupture could have been completely isolated by closing only V1AR and V3AR, plus the subsequent automatic closure of V2AR as a result of the minimum pressure set point (355 psig).

Abstract A pipeline simulation system is an excellent tool for providing training to operators, planners and dispatchers. It allows creating hydraulic scenarios to teach about pipeline behavior and to test operator's responses to abnormal conditions. In 1998, LICENERGY started an ambitious project of implementing a trainer system for the three major multi-product pipelines operated by the Colombian Petroleum Company, Ecopetrol. The main target was to provide a simulation system that would act as a mockup of the real pipeline, receiving operator/instructor commands and sending calculated data to the SCADA system. The data is displayed in SCADA's user interface screens identical to the ones used by the operator in normal pipeline operation. Most of the SCADA functions should be available as if the user was operating on the real SCADA system. This paper explains the process of implementing the system, its functions, limitations and the experiences gathered during all phases of the project. Ecopetrol's Multi-Product Pipeline System Overview Ecopetrol operates more than 3,300 miles of pipeline transporting crude oil from the production fields to the refineries and export terminals, and refined products from the refineries and import terminals to the consumption centers and to major distributors. The refined products include gasoline, kerosene, diesel fuel, aviation gas, LPG and others. The trainer project covers only 3 pipeline sections (about 730 miles of pipeline) of the total pipeline system. These sections are: Refined products pipeline from Pozos Colorados to Galan Refined products pipeline from Sebastopol to Yumbo Refined products pipeline from Puerto Salgar to Bogotá The trainer system is part of a global project that includes SCADA, instrumentation, telecommunications, simulation-based leak detection, batch tracking and scraper tracking. The trainer is not only used to train personnel, but also to analyze possible operating strategies or to design contingency plans. Scope of the Trainer Simulation Model The concept behind the Trainer is to create, in the SCADA system, a virtual environment where the field instrumentation data is replaced by model-generated data. Boundary conditions to drive the hydraulic model are provided either by the instructor from the Instructor console, or by the operator via regular SCADA commands, e.g. open valve, start pump, change setpoint, etc. The SCADA Trainer database is an off-line copy of the real-time SCADA database. The analog and bdigital points for the Trainer are similar to a subset of the SCADA signals for the field instruments (e.g. pipeline pressures, flow rates, temperatures and densities, valve positions), but these signals are calculated points whose values are provided by the Trainer Model. A new set of station schematic displays is required on the SCADA side of the Trainer. These displays are very similar in appearance to the station displays used to operate the real pipeline. The only difference is that the dynamic fields are linked to simulated points for those points handled by the Trainer Model.

ABSTRACT Praxair currently has a development program in place to automate the control of its pipeline systems using proprietary control technology. Closed loop control offers a number of benefits over current manual pipeline operation, including continuous analysis of the pipeline and improved decisions regarding which plants to load or unload as pipeline demand changes. These benefits lead to more efficient pipeline operation and maximized profits. As closed loop control of pipeline networks is a relatively new problem for Praxair, it is important to ensure that the techniques being applied are well understood and tested prior to any field implementation. Towards this end, a dynamic pipeline simulation was used in place of the real pipeline during control system development. This allows for rigorous testing of the pipeline control methods without the risk associated with testing on the actual pipeline. Furthermore, the pipeline control simulation integrates dynamic pipeline models with Praxair's standard SCADA software, resulting in a realistic representation of the actual on-line control system, which is used for further system development, operator training and offline analysis. Introduction As one of the world's largest industrial gas manufacturers, the bulk of Praxair's revenue comes from the sale of oxygen, nitrogen, and other industrial gases. These products are then used as feedstock for a variety of industries including steel, petrochemical and semiconductor manufacturing. The majority of Praxair's sales result from the products produced in its Air Separation Plant's (ASP). The pipelines fed by ASP's are the focus of this paper. Figure 1 shows a simplified diagram of an Air Separation Plant. Compressed air feeds a series of heat exchange and distillation units, operating at cryogenic temperatures, to separate the air into its individual components of oxygen, nitrogen and argon. While the argon is typically produced in relatively small quantities as a liquid, the other products can be produced as liquid or gas depending on the prevailing market and/or customer needs. Figure 1 shows the simplest Praxair/customer relationship, where it is assumed a single ASP is feeding customers directly connected to that plant. In this scenario, the goal of ASP operation is to produce just enough oxygen and nitrogen gas to meet the local customer demand. As shown in Figure 1, liquid products are produced simultaneously from the same plant and are stored in tanks at the site. The liquid products are distributed by trailer or railcar to customers with on-site liquid storage tanks. While the available liquid storage is used to buffer fluctuations in liquid demand, little additional gas storage capability exists. Therefore, the ASP production must be continuously adjusted to account for gas pipeline demand changes. To ensure that operating costs are continually minimized, the ASP usually has a closed loop control system that monitors pipeline pressures and automatically adjusts production as customer demands change. In addition to meeting customer demand, the individual plant control system will ensure that safety, purity and other constraints are not violated as production levels change.

ABSTRACT A simulation model is being developed to track the operation of a two-phase wet gas pipeline in Indonesia. The on-line model continually receives SCADA updates assuring accurate conformance to the actual pipeline. The information generated by the model supports the Pipeline Management System (PMS) applications, which include Inventory Management, Line Pack, Over/Under Pressure Analysis, Instrument Analysis, and Look-A-Head Analysis. The simulation model is capable of simulating gas pipelines, liquid pipelines, as well as transient operation in either single or two-phase. The simulation model is run in conjunction with the SCADA system. All alarms are presented to the operator through the SCADA alarm management system. All data, trends, and profiles from the simulation model are also presented to the pipeline operators through the SCADA graphics management system. The paper concludes with a discussion of the dynamic testing of transients in the two-phase model when multiple components are present. West Java Gas Transmission Pipeline Overview The West Java gas transmission pipeline was put into operation in 1977. The 280 mile (740 km) pipeline network, transports natural gas through cities and suburbs while serving heavy industrial customers; fertilizer plants, cement plants, steel plants, power plants and other industries in West Java. The onshore pipeline network is composed of 9 sources/inputs, 5 compressor stations and 18 consumers/outputs receiving up to 400 MMSCFD of natural gas. The pipeline, delivering gas in an east to west direction, having a maximum design pressure of 720 psi (50 kg/cm2) is composed of X52 and X42 grade pipe segments. The diameter of these segments varies from 8 to 32 inches, with most of the mainline piping at 24 inches. The pipeline is externally coated, cathodically protected and buried 3 to 5 ft (1 to 1.5 meters) underground. 2 Compressor stations are composed of centrifugal units driven by gas turbine engines. High pressure and low-pressure sources supply gas from both onshore and offshore gas fields. Wet gas is mixed with dry gas after the scrubbing and dehydrating processes. Gas component information is available at source and consumer locations via chromatography readings. System Architecture Data from the individual RTU's will be polled and gathered by the communications server of the SCADA system. This data is presented to the simulation model at the same time it is presented to the Graphics and Alarm systems for the operator to see. The simulation model processes the data and performs its application calculations every quarter of a second. Upon completion of the application calculations, the model submits the results to the Graphics and Alarm systems allowing the operator to interact with the simulation model and respond to alarms exclusively through the regular operator console and environment. The operators will never interact physically with the Pipeline Management System (PMS) computer that houses both the model and the PMS applications. Data from the master or host SCADA communications server will be submitted to the PMS computer. Output from the PMS computer will be sent back to the host computer.

ABSTRACT In a few short years the Internet has grown from a relatively obscure technology to a widely used and important source of information. Along with the advances in Internet technology have come increased opportunities for "logging in" and telecommuting. Telecommuting provides an excellent opportunity for the gas industry to save money in overhead costs while increasing worker productivity. The Internet allows fast, remote compressor performance analysis if the user is equipped with the right performance enhancing technology. A need exists in the industry for technology that allows portable, rapid, detailed and graphical analysis of real time compressor performance from current SCADA input data. To be truly portable, this technology would have to be capable of running on a laptop computer (or PC) and would have to work from any regular telephone connection. The authors have developed technology that enlists the Internet lntranet to solve many of the problems associated with real time compressor analysis. Using a laptop (or desktop) computer equipped with the software illustrated in this paper, authorized personnel can "dial in" and generate a detailed and graphical "real time" description of the performance of any compressor on the Northwest Pipeline Corporation (Northwest) SCADA System. this paper, "real time" data refers to the latest SCADA data available). This process (In typically takes less than 5 minutes. This paper starts with a discussion of the Internet and the World Wide Web, followed by a description of the evolution of the reciprocating and centrifugal compressor modeling programs at Northwest. RECIP (the off line reciprocating compressor program) is illustrated. Then, RTMCalc (the "real time" Internet/lntranet reciprocating compressor program) is portrayed. After showing the World Wide Web site, some conclusions are offered and potential future developments are discussed. The Internet is a world wide computer network that connects millions of computers and tens of millions of user into one vast communications system. The Internet is often referred to as the "network of networks", in that it is the main network that interconnects all the networks in the world together. 2.1 History of the Internet The origin of the Internet can be traced back thirty-five years. In the early 1960s, the U.S. Department of Defense (DOD) was concerned how to preserve the United States' communications infrastructure in the event of nuclear war. The DOD realized that traditional switch-based communication systems where switching equipment dedicates a specific circuit for each communication session were particularly vulnerable to disruption due to their very centralized control. If the central circuit switching systems were damaged, the entire communication system would become useless. In 1962, the RAND Corporation, a think-tank, conceptualized a communications methodology called packet switching. Packet switching enables the transmission of data to be broken into smaller units, or packets, and sending the individual packets over the communications lines. Each packet includes an address, to identify the destination computer, and a time stamp to enable the destination computer to assemble the packets into the format of the original data.

ABSTRACT Centra Gas, a Local Distribution Company in Winnipeg, Canada, has installed an integrated transient simulation model and SCADA system. This is a completely Windows NT@ pipeline operating system that allows the simulation model to recall historical transient pipeline conditions and replay historically saved SCADA data from a transient. This system does not require or assume steady state conditions. The system is designed to allow operators to review the transient as it occurred, or to intervene and train on their response to the transient condition Centra Gas Manitoba Inc. Centra Gas Manitoba Inc. is the sole natural gas distribution company for the entire province of Manitoba, Canada. The company provides naturai gas service to approximately 230,000 customers in more than 90 towns and locations throughout the province. Centra Gas Manitoba Inc. is a wholly-owned subsidiary of Westcoast Energy Inc. The company's headquarters are located at 444 St. Mary Avenue in Winnipeg, with regional offices in the cities of Brandon, Dauphin, Portage la Prairie, Selkirk, Steinbach, and Winkler. It's operations are regulated by the Public Utility Board of Manitoba. There are more than 600 employees working for Centra Gas Manitoba. These employees are responsible for the supervision of the safe operation, maintenance, and gas distribution of the pipeline system, and providing the very best in customer service. Distribution Network The Centra Gas pipeline system is a combination of both transmission and local distribution networks. The natural gas is received from the Tram+Canada Pipeline system and is the sole natural gas delivery system for the population of Manitoba. Its operations include the management of more than 5,300 kilometers (3,180 miles) of transmission mains and distribution pipelines. The customer base for Centra Gas is made up of approximately 70% industrial and 30% residential consumption. The pipeline network delivers natural gas with significant seasonal swings in demand, the capacity ranges from 5.38 Million Cubic Meters per day with 1.0 Million being delivered to customers and the remaining 4.38 Million being placed in storage during the summer to approximately 16.0 Million Cubic Meters being delivered to customers during the winter months. SCADA Replacement Centra Gas has begun a process of modernizing and upgrading its system to provide additional capacity and monitoring of existing stations. The legacy SCADA system is approximately 11 years old and was designed and installed by Fisher. The recent announcement by Fisher that they would no longer support their SCADA systems installed base and that they would no longer implement SCADA systems proved to be an impediment to the planned upgrade program. The present pipeline system uses two different types of monitoring devices, ROMET EVC and HP 48000 RTU's. Centra Gas is replacing the ROMET RTU's with newer Mercury EC-AT RTU's and will be replacing the HP 48000's in the near future. The Fisher SCADA system is a closed system and does not support the communications protocols for the new RTU's.

SUMMARY Pipeline hydraulic and transient studies assisted the design of facilities to increase the capacity of the Saudi Aramco East/West pipeline system. The capacity of pumps and the power of their combustion gas turbine (CGT) drivers limited existing pipeline throughput. The hydraulic capacity increased by 50%. Hydraulic studies identified additional pipeline looping and pumping capacity to be added to the pipeline system. Transient studies predicted that operational upsets, such as a trip of a pump station, cause excessive surge pressures in the pipeline system. New surge relief stations and an increase in capacity of existing surge relief stations was mandated to protect the pipelines at the higher flow rates. The surge studies identified the optimum location of six surge relief stations. Pump station trips are highly disruptive to normal pipeline operations. A trip of a pump station at flow rates above 70% of design capacity may cause surge relief stations to operate, downstream pump stations to trip on low suction pressure, and upstream pump stations to trip on high discharge pressure. Pipeline flow rates reduce to zero as a result of these cascading series of events. Transient studies identified pump station operating strategies to minimize pump station trips and maximize pipeline throughput at high flow rates. Following an upset, a Supervisory Control and Data Acquisition (SCADA) computer system transmits commands to Distributed Control System (DCS) computers located at the pump stations and pressure reducing stations. The SCADA and DCS computers invoke a series of actions to minimize the effects of upsets. Set point changes, implemented by the DCS computers, adjust pressures and power levels. They prevent the pipeline transient pressures from exceeding the relief set points of the surge relief stations and the trip set points of the pump control systems by reducing the speed of the CGT driven pumps. Relief valves at surge relief stations do not open and the remaining pump stations continue to operate. An additional series of SCADA and DCS improves control of the pipelines communication failure and pump station operations. INTRODUCTION Actions during by pass The Saudi Aramco East/West Crude Pipelineconsists of two pipelines originating at AbqaiqPlants and terminating at Yanbu crude oil terminal. Crude oil storage tanks located at an initiating pump station receive the Arabian Light crude transported from Abqaiq Plants. Eleven pump stations transport the crude oil to Yanbu. The eleven pump stations are similar except for infrastructure and other support facilities. 1.0 COMPUTER MODELING OF THE EAST/WEST PIPELINE SYSTEM 1.1 SOFTWARE PACKAGES Several software packages assisted studies of the pipeline system during four phases of the project. The four phases encompassed hydraulics and surge studies during Conceptual Analysis, the Design Basis, Project Proposal, and Detailed Engineering. Simulation Sciences Inc. software package PIPEPHASE, and Scientific Software Intercomp Inc. software package TLNET assisted hydraulics analysis. Stoner Associates Inc. software package LIQT, and the Scientific So&are Intercomp Inc. software package TCON assisted surge studies. The software packages TCON and PIPELINE SIMULATOR also assisted control systems analysis during rampdown studies.

ABSTRACT This paper examines the simulator-based training methods employed in the oil and gas pipeline industry to develop and maintain competent pipeline operators. The most popular methods are described, and the impact of simulator-based training over traditional methods is examined. The simulator-based methods that are described come from a variety of sources. These methods include: PC-Based Training Videodisc-Based Training SCADA-Hosted Training Workstation-Based Training These methods represent fundamental approaches to implementation of simulator based training, and should not be assumed to represent actual products available from vendors. In some cases, vendor products are hybrid implementations of the fundamental approaches. The training requirements are examined based on the available literature in the human resources field and the appropriate use of simulation technology in training is also described. 1.0 INTRODUCTION The pipeline is most economic and safest method of moving crude oil, petroleum products, natural gas and other industrial fluids from the point of production to the point of consumption. Safety and economics are obviously not automatic and must be thoroughly considered for each aspect of the pipeline life cycle: design, construction, operation and retirement. Safety and economics are also conflicting objectives: increasing safety margins means increasing pipe wall thickness, lowering MAOPs, curtailing deliveries while improving economics implies the opposite. The successful pipeline company must negotiate a balance between the economic and safety requirements. Within this scheme of conflicting objectives, the job of the pipeline operator has special responsibilities which demand a requirement for training procedures that are both rigorous and effective. Furthermore, the complexity of fluid behavior and pipeline operation make Within this scheme of conflicting objectives, the job of the pipeline operator has special responsibilities which demand a requirement for training procedures that are both rigorous and effective. Furthermore, the complexity of fluid behavior and pipeline operation make computer simulation an ideal component of training course implementation. In an attempt to present a clearer picture of the demand 1 supply situation currently prevalent within the industry with respect to training, a survey was performed that comprised a search of the technical and commercial literature. In addition, selected companies were contacted directly. The primary objective of the survey, the results of which are detailed in this paper, was not to develop a comprehensive report but rather to provide a picture of the ongoing direction of training. 2.0 THE REQUIREMENTS OF THE INDUSTRY 2.1 Training of Control Room Operators Training in this paper means training of pipeline operators, also referred to as controllers or dispatchers. These people are the ones in the control room who, through the Supervisory Control and Data Acquisition (SCADA) system, make the decisions on how to control the pipeline.

ABSTRACT SIRGGAS is a computer program for simulation of the steady state and transient behavior of single phase fluid (principally gas) in pipeline networks. SIRGGAS is in use by most operators of high pressure long distance natural gas pipelines in Australia. Recently SIRGGAS has been installed on the Leeds and Northrup Supervisory Control And Data Acquisition (SCADA) computer at the Australian Gas Light Company control centre in Sydney. Each minute the SCADA provides pressures, flows, etc measured at Moomba, Newcastle and other places on the NSW gas pipeline network. SIRGGAS uses this information to simulate the previous minute. Thus an up-to-date simulation of the network is available at all times. The purpose of this is to provide to the operator up to 300 quantities that are calculated by SIRGGAS, many of which such as linepack (mass of gas present in the pipeline), are not easily measured; and to provide a starting state to simulate the operation of the network over the next 16 days. This is done routinely once each day, and at other times as requested by the operator. The facility is designed for routine operator use and all interaction with the model is through normal or specially developed SCADA functions. The development and use of the SIROGAS facility is described and comparisons between measured, Tracking and Prediction results made which show that when the model receives valid data, good agreement is obtained with actual operation. Several events resulting in invalid data being passed to the model are discussed. BIOGRAPHY OF AUTHORS William J.Turner Senior Project Manager CSIRO Division of Mineral and Process Engineering, PMB 5, Menai, NSW 2234 Australia Bill Turner graduated with honours in theoretical physics from the University of Tasmania in 1961. After working in the UK and Canada, he became immersed in research and design for nuclear reactors with the Australian Atomic Energy Commission. In 1982 this led him to apply his mathematical methods developed for nuclear reactor ‘loss of coolant accidents’ to gas flow in pipeline networks. He and this activity were transferred to the principal Australian government research body CSIRO in 1982 where he heads the Fluid Mechanics area in the Division of Mineral and Process Engineering. Since then he on behalf of CSIRO has supplied software and other assistance to the gas pipeline industry in Australia, as well as supervising a wide range of fluid mechanics theoretical and experimental work for the Australian mineral industry. Prue A. Maguire Scientist CSIRO Division of Mineral and Process Engineering, PMB 5, Menai, NSW 2234 Australia Prue Maguire graduated from Macquarie University in 1986 with a Bachelor of Science in mathematics and computer science. Since 1987 she has been working for CSIRO and is involved in the programming and development of software for the simulation of gas pipelines. Chris Smith Leeds and Northrup (Australia) 18 Mandible St. Alexandria, NSW 2015 Australia Chris Smith holds a degree in electrical engineering from the University of Sydney

Summary This paper addresses one solution to a critical training problem for gas control operators. Gas control training has traditionally been achieved through a apprenticeship dependent upon experienced controllers training younger, newer personnel. In 1987, Equitable Resources' retiring Superintendent of Gas Control Charles "Chuck" Felker realized that ERI was facing a serious decline in the combined years of experience of their gas control personnel, from 225 years in 1980 to just 59 years projected for 1990. Thus ERI began to study and search for ways to improve their system of gas control tralning. In 1988, MindT3ank, Inc., a Pittsburgh interactive simulation company, was contracted to create a simultator/trainer to teach SCADA and pipeline control, ~o~ati omanna gement, and emergency response. This solution addressed the loss of experience by capturing this valuable wisdom within simulation sessions. The creative and technical challenges both EX1 and MindBank faced while producing SOLO (Simulated On-Line Operations) are discussed in detail. ABOUT EQUITDTABLE RESOURCES. INC. Equitable Resources, Inc. is an integrated energy company generating $500 million in revenues through two segments: Energy Resource and Utility Service. The Energy Resource segment is responsible for the exploration and development of natural gas resources. The Utility Service division purchases, gathers, transports, stores, and distributes natural gas to more than 263,000 retail customers in Pennsylvania, West Virginia, and Kentucky. Pipeline operations for the transmission and distribution sectors for Pennsylvania and West Virginia are conducted from a central gas control center located in Pittsburgh, Pennsylvania. Control of this piping network, with its associated valves, regulators, and compressor stations, is accomplished with a PC-based Supervisory Control and Data Acquisition (SCADA) system. At the heart of the SCADA system are nearly 250 telemetered gas pressures, flow and/or digital status data points, as well as 130 valves, regulators, and odoff control circuits. ERI's SCADA contains 800 alarm settings for telemetered data that represent practical operating limits for over '7,000 miles of pipeline. These alarm levels were established by one individual, Howard Shively, over a 40-year career in gas control. To research these alarm levels now, beginning with a blank map, would be an horrendous task, and illustrates the importance of capturing as much knowledge and experience from the departing controllers as possible, so that the younger, newer controllers can benefit from their experience. The SCADA system is manned 24 hours a day by a staff of six full-time and two part-time gas control operators. The two part-time operators are contract employees who retired several years ago under an early retirement program designed to trim operations. Most of the gas controller's job is routine. However, it is the routine nature of the job that creates the training problem. Few operators are fully prepared for emergencies when they do take place. Even under normal circumstances, there are many stressful elements to manage.

ABSTRACT The amount of gas transported for others by Colorado Interstate Gas Company (CIG) more than tripled during the period of 1984 to 1988. The amount of gas sold by CIG fell more than 60% during the same period. Changing roles from merchant of natural gas to transporter has presented a challenge to those who operate and control the pipeline. CIG has responded to the challenge by developing an integrated system of programs to schedule, model and monitor transportation and sales gas. Based on a DEC VAX 111780 computer, the system consists of a transportation gas information management system, a Supervisory Control and Data Acquisition (SCADA) system and Gas Control Planning System. 1 THE CHANGING REGULATORY ENVIRONMENT May 1985 marked a turning point in the interstate natural gas pipeline business. Up to that point pipelines acted as merchants of gas. Pipelines purchased gas from producers then moved the gas to market and resold it. The Federal Energy Regulatory Commission (FERC) changed all that with its Notice of Proposed Rule making, Order 436. The new regulations have transformed most major interstate gas pipelines into common carriers of natural gas. Colorado Interstate Gas Company has made the transition from merchant to transporter, accepting a blanket open access certificate under FERC Order 500 in 1988. The change of roles has had a dramatic impact on pipeline operations. As a merchant of gas, CIG forecasted all its loads and scheduled all supplies. Gas transported for others was a relatively small segment of the business. Supplies were scheduled to meet loads while taking storage requirements into account. The entire process was under virtually complete control of CIG. Volumes transported by CIG for others tripled from 1984 to 1988. Sales gas has fallen 60% over the same period. Local distribution companies (LDCs) and other traditional sales customers contract with producers to purchase gas, then contract with CIG to transport it. In addition, volumes moving on to interconnecting pipelines for third parties have increased substantially. Much of the control over where gas moves and in what quantities has passed from CIG to the companies contracting for transportation services. 2 TERMINOLOGY As with any business, gas transportation has its own vernacular. For the sake of clarity a few of the terms most often used should be defined. Receipts are volumes entering the CIG main line. Deliveries are volumes leaving the main line. Shippers are those parties who have contracted for transportation service with CIG. Nominations are specific requests for transportation service which CIG receives from shippers. Transport gas, transportation gas and T&E gas are all the same thing. It is gas which CIG transports but is owned by someone other than CIG.

1.0 INTRODUCTION This paper describes a Sour Gas Leak Detection System implemented by Novacorp International Consulting Inc.'s Pipeline Software Group. The emphasis of the paper is on the design considerations made in supplying a leak detection system for a gas pipeline system. The paper also presents the estimates of performance obtained from preliminary studies. The project's main goal was to provide reliable and accurate leak detection at low cost. That meant providing better accuracy than a simple volume balance at a cost considerably less than a transient model based leak detection system. A Compensated Volume Balance approach was selected since it is cost effective and sufficiently accurate when the pipeline is well instrumented. The pipeline's SCADA system design was not yet finalized so that additional pressure and temperature instruments could still be added to accommodate the leak detection system. 2.0 PIPELINE DETAILS 2.1 GEOGRAPHY The pipeline is located in a sparsely populated area of Central Alberta, Canada. It is close to a small town and a provincial campsite and crosses a river at one point. The effect of a prolonged leak of sour gas in this environmentally sensitive area would be disastrous. Therefore, the steps taken by the client to protect the public and the environment are commendable. 2.2 PIPELINE CHARACTERISTICS The pipeline is 44 miles long and 12 inches in diameter with a 0.35 inch wall thickness. Elevation of the pipeline ranges from 3250 to 4500 feet. Depth of burial is approximately three feet. The pipeline is extremely well instrumented with pressure measurements spaced from one to six miles apart. Flow, pressure and temperature are measured at the inlet and outlet ends of the pipeline with pressure and temperature measured at four intermediate block valves and pressure only measured at another eight intermediate block valves. The following instrumentations accuracy is assumed: Measurement Accuracy (%) Range pressure 0.5 0-2200 Psig NOTE: Accuracy is given as a percentage of full range. The SCADA system receives data fiom each of the RTU's along the pipeline every two minutes . 3.0 LEAK DETECTION METHODOLOGY 3.1 SIMPLE VOLUME BALANCE On the low end of the performance scale is the Simple Volume Balance leak detection method. In its simplest form leaks are detected by comparing the volume into and out of the pipeline over time. This method might be considered for an incompressible fluid such as crude oil but is highly insensitive for gas pipeline application especially in short time fiames. 3.2 TRANSIENT MODEL BASED LEAK DETECTION On the other end of the scale of leak detection algorithms is the Transient Leak Detection method. This method can provide a highly accurate means of detecting leaks in a liquid or gas pipeline. This method of leak detection comes in various forms but the basic principles are the same. The modelled state of the pipeline is used to determine the change in line pack between flow measurements.