ATCO ELECTRIC
With a lot of hard work, ATCO Electric's Y2K program has met all key milestones.
As of the end of April 1999, all critical and high-priority systems in our generating stations and the transmission and distribution systems are Y2K ready. In addition, key systems in all three areas were operating as if it were the year 2000. This includes the control systems in the coal-fired units, the transmission SCADA system and the reclosers on the distribution system. As of the time of writing of this article, remaining medium- and low-priority systems were targeted to be Y2K ready by the end of June.
ATCO Electric is one of the first utilities in North America to have its transmission system ready for the millennium. During April 1999, system clocks at 160 substations, our system control centre, the SCADA system and all 200 telecommunication sites were advanced to December 31, 1999. The clocks were then allowed to advance normally to January 1, 2000 and did so without affecting service to customers. Indeed, there have not been any Y2K-related problems affecting the delivery of power as a result of our program of advancing system clocks.
Among other noteworthy events and efforts:
Research in Alberta indicates that customers are not panicking about Y2K but there may be an underlying concern. We have indicated to customers that while there are no guarantees, we do not expect there will be significant problems affecting service to customers. Our general advice: make the usual preparations in case of any unexpected service interruption.
ATCO Electric, formerly Alberta Power Limited, serves more than 164,000 electric customers in northern and east-central Alberta. We generate about one-fifth of the province's electric energy, most of it from three major coal-fired stations. The company owns and operates more than 8,000 km of high-voltage transmission lines and 45,000 km of distribution lines.
BC Hydro: Preparing for the millennium
BC Hydro is a technology based company. We use computer technology to operate generating facilities, substations, and control centres. Just like other companies world-wide, we need to address our Year 2000 challenges to continue to be able to use that technology to provide our service. To that end, we have a comprehensive Year 2000 project in place, which we started working on in 1994. From the work we've done to date, we do not expect power outages due to Year 2000 related issues within our system. BC Hydro recognizes electricity is a mainstay of homes and businesses, and will do its utmost to "keep the lights on" before, during, and after the Year 2000 transition.
Utilities Working Together for British Columbians
BC Hydro is a founding member of the B.C. Utilities Year 2000 Forum, which includes BC Gas, BC TEL and Centra Gas. We established the Forum last year to identify areas of interdependencies and share mutual solutions to Year 2000 issues we have in common.
The utilities meet regularly to share technical and procedural information about our respective Year 2000 projects, identify areas where we depend on each other's services and develop common solutions to any Year 2000 problems in these areas. We are also coordinating our contingency planning, and working together on a simulated Year 2000 emergency response exercise.
Through the coordinated approach of the B.C. Utilities Year 2000 Forum, we are working hard to help ensure that British Columbians can continue to depend on our essential services into the next century and beyond.
Becoming Year 2000 ready
The first step was to conduct a thorough inventory of our equipment. We went to every generating station, every substation, every control centre, and every Hydro building across the province to prepare an inventory of devices that might be Year 2000 sensitive. These are devices that contain microprocessors (embedded systems) or computers. Of the more than 250,000 electrical devices and pieces of equipment in our system, the majority are analog or electro-mechanical, which means they do not have Year 2000 implications. Our inventory yielded about 8,000 devices which contain microprocessors and computers.
Our next step was to conduct an assessment to determine the potential for impact on our system if any of those 8,000 devices failed or malfunctioned. About 3,300 of those devices were rated as potential for high impact, in that they could have a direct impact on public safety, the environment, or our ability to generate and deliver electricity. Stringent testing has identified most of these 3,300 devices as Year 2000 ready, about 250 high impact devices were not Year 2000 ready and needed to be fixed, upgraded or replaced to ensure that all our most important systems will be Year 2000 ready. We're well on our way in our remediation effort, and the high impact devices will be fixed and tested by May 31, 1999.
Cooperating with other utilities
BC Hydro's system is part of a larger, interconnected transmission grid system that covers B.C., Alberta, and the western U.S. This system is governed by the Western System Coordinating Council (WSCC), which coordinates reliability standards all member utilities must meet. We are working closely with the WSCC and our grid partners by sharing and coordinating solutions to Year 2000 issues, systems operating plans, contingency plans, and other relevant Year 2000 information. A key aspect of Year 2000 readiness is coordinating our work with others. We are working with a number of groups, including:
Although we do not expect service disruptions due to Year 2000 related issues, factors outside our direct controls, such as severe weather conditions or problems experienced by grid partners, prevent us from guaranteeing uninterrupted service at any time. Because emergencies can occur unexpectedly , contingency planning is part of our everyday business. We are building on our existing contingency plans to develop Year 2000 specific contingency plans as a precautionary measure during the critical time period. Examples include:
staffing all key facilities, most of which are normally automated
minimizing energy transfers over the grid interties
not planning any maintenance or equipment outages
having additional staff on hand to operate key systems manually if required
operating the electric system conservatively to ensure flexibility
coordinating BC Hydro contingency plans with grid partners' plans
exercising our emergency response and communication procedures
Working with customers
BC Hydro is working closely with its industrial customers as these customers can potentially impact the electric system due to amount of electricity they use. We held one workshop for our large customers, and plan on holding at least one more. Those who have already not done so should contact their BC Hydro account manager so that we can coordinate our Year 2000 activities.
The ENMAX Y2K Project
The Year 2000 problem, while technical in nature, is primarily a business problem and at ENMAX it is being managed as such. Managers of all ENMAX's business units are responsible for staffing and execution of Y2K readiness projects in their areas. The role of the ENMAX Year 2000 Program Office is to fund, coordinate and monitor company-wide progress towards readiness. It also fills a quality assurance role, providing individual business units with information and assistance in implementing best Y2K testing practices. Across the company, we have identified 2017 Y2K inventory items of which 479 are classified as having extreme or high business impact.
The size of the dedicated Y2K team at ENMAX varies as different groups mobilize for different stages of the project. The core team size is presently at 15. ENMAX expects to spend roughly twelve million dollars over the three years of the project. Many of these expenditures relate to the replacement or upgrade of equipment that was reaching the end of its useful life anyway, and are therefore a normal cost of doing business.
Project Progress
The ENMAX Y2K Program has been up and running since June of 1997. The readiness of mission critical systems was addressed first. These include:
ENMAX expects to meet the June 30 milestone put forward by the North American Electric Reliability Council for the readiness of mission critical systems of electric utilities. Our standard of readiness extends beyond technical issues of system functionality to include the development of operational strategies to provide services even in the case of Y2K-related system failure either inside or outside the company.
For its critical engineering systems, ENMAX successfully completed integrated testing on May 5, 1999. This test checked the concurrent functionality of several mission critical substation and communication devices and the SCADA system over several Y2K rollover dates. Although several utilities are performing similar "end to end" tests at their generating plants, very few transmission and distribution utilities are performing such tests.
Supply Chain Management
ENMAX wants to ensure that Y2K issues among its suppliers and its customers do not cause operational problems for the utility. A key focus for an electrical transmission and distribution utility like ENMAX, is the availability of power from generation utilities. To address this largest supply risk, ENMAX is working closely with its electrical industry partners in Alberta sharing test results and leveraging common Y2K expertise.
ENMAX has identified other key business dependencies on banking, natural gas and telecommunications suppliers and plans to maintain supply chain discussions with these companies through to the end of 1999 in order to obtain the most up-to-date supply and contingency planning information.
Because the distribution of electricity is a question of balancing supply and demand, our supply chain also extends downstream of us to our customers. We are communicating with our customers about their operational plans for the Y2K rollover in order to predict our load for the period as accurately as possible.
To maintain our Y2K ready environments, we have implemented a comprehensive "clean management" policy and procedures to ensure that any new systems or changes to the existing systems do not introduce new Y2K related risks.
Planning for the Unexpected
Contingency planning at ENMAX includes three components: emergency preparedness, emergency response and business restoration. A number of scenarios are being developed at contingency planning workshops, exploring emergency situations with various degrees of probability and severity. Our emergency response planning was 93 per cent complete as of May 25, 1999. The milestone for completing business restoration planning is November 1, 1999.
ENMAX will participate in the drills organized by the North American Electric Reliability Council (NERC). ENMAX is also actively participating in the Y2K Operational Preparedness Team organized by the Transmission Administrator for Alberta. In addition, ENMAX is taking part in the Y2K preparedness efforts coordinated through the provincial and municipal emergency services.
Preparing for the Next Millennium at Hydro-Québec
Since 1995, Hydro-QuŽbec has been working diligently to adjust its equipment and computer systems to ensure that the transition to the year 2000 will not cause any inconvenience to customers or employees. Furthermore, the utility requires that its suppliers and large-power industrial customers provide proof of their Year 2000 compliance.
Hydro-Québec drew up an inventory of all computer systems and components that might be affected by the changeover to the next millennium. It then undertook a process to convert and certify each date-sensitive system or component that was not Y2K-compliant. By the end of June 1999, the utility will have completed all the work deemed essential to its Year 2000 project.
After analyzing the residual risks, Hydro-Québec designed a set of preventive measures which are contained in a contingency plan. This plan will be gradually implemented between June and December 1999, at which time everything will be in place for the changeover to the year 2000.
1996: Inventory
The results of the inventory showed that 3,825 computer systems and components were classified either critical or manageable:
1997: Project Organization
The project is directed by a Year 2000 steering committee, chaired by the Deputy Chief Executive Officer. Members include the President of the Transƒnergie division, Executive Vice Presidents and Senior Directors.
A project head, reporting to the Year 2000 steering committee, coordinates the work of some 20 teams responsible for conversion and certification. These teams cover all company activities.
Two technical exchange round tables - one on automated control systems and the other on computing - provide a forum for different specialists to discuss technical issues and coordinate their efforts.
The Year 2000 project, launched in 1996, is one of the utility's top priorities. Senior management is actively involved in the project and closely monitors its progress.
The total budget is $61 million. However, the cost of the project will have no impact on customer bills. Almost 300 people are working on the Year 2000 project.
1997: Conversion Plan
The Y2K bug is not just "bad news"; there are side benefits as well. For instance, it allows:
1998: Conversions and Tests
The conversion of products (computer systems, software, embedded chips, automated controls and hardware), along with an upgrade of the technological infrastructure, were completed at the end of 1998.
All items identified as critical or manageable must be submitted to a certification process, in order to ensure they are indeed Y2K-compliant.
1999: Integration Tests and Final Adjustments
Hydro-Québec has set aside part of 1999 to test the integration of various components and make last-minute adjustments. To maximize its level of preparedness, the utility is taking the following actions:
Hydro-Québec's action plan for the year 2000 also takes into account the initiatives of its customers and suppliers. The utility must ensure that all its business partners have taken the necessary steps for a smooth transition into the next millennium.
Any supplier or consultant wishing to do business with Hydro-Québec will have to prove in its tender documents that its goods or services are Y2K-compliant.
Finally, with respect to preventive measures and to ensure that its customers and suppliers are ready for the year 2000, Hydro-Québec has met with representatives of neighboring power systems, independent power generators who are connected to its system, as well as some 250 large-power industrial customers. The utility is also a participant in two simulation exercises organized by the North American Electric Reliability Council (NERC). The first drill, which was held on April 9, produced excellent results. A second drill is scheduled for September 9, 1999.
Le passage à l'an 2000 à Hydro-Québec
Depuis 1995, Hydro-Québec s'affaire à convertir ses appareils et systèmes informatiques afin de franchir le cap de l'an 2000 sans inconvénient pour sa clientèle et son personnel. De plus, l'entreprise exige de ses fournisseurs et de ses clients majeurs l'assurance de leur conformité à l'an 2000.
Hydro-Québec a inventorié l'ensemble des produits pouvant être touchés par le passage à l'an 2000 et a procédé à la conversion et certification de tous ceux ayant des fonctions de dates et n'étant pas conformes à l'an 2000. L'entreprise aura terminé les travaux essentiels à la réalisation de sa mission à la fin de juin 1999.
Après avoir fait une analyse des risques résiduels, elle a élaboré un ensemble de mesures préventives contenues dans un plan de contingence qui sera mis en place progressivement de juin 1999 à décembre 1999. Tout sera alors en place pour le passage à l'an 2000.
1996 : Inventaire
Les résultats de l'inventaire des quelque 3 825 produits classifiés comme étant critiques et gérables sont les suivants :
1997 : Organisation du projet
Le projet relève du Comité directeur An 2000, présidé par le directeur général adjoint. Ce comité est composé du président de la division TransÉnergie, des vice-présidents exécutifs et des directeurs principaux.
Un chef de projet, relevant du Comité directeur An 2000, coordonne les activités d'une vingtaine d'équipes responsables de réaliser les travaux de certification et de conversion des produits. Ces équipes couvrent l'ensemble des activités de l'entreprise.
Deux tables d'échanges techniques, l'une pour les automatismes et l'autre pour l'informatique, permettent aux différents spécialistes d'échanger sur des points techniques et de coordonner leurs efforts.
Le projet An 2000, enclenché en 1996, fait partie des priorités d'Hydro-Québec. La haute direction y participe activement et exerce un suivi serré de l'avancement des travaux.
Le budget global est de 61 millions de dollars. Or, le coût du projet n'aura pas d'impact sur la facture des clients. Près de 300 personnes ont été affectées au projet.
1997 : Plan de conversion
L'arrivée de l'an 2000 ne présente pas que des inconvénients. C'est un événement qui a l'avantage d'offrir de nouvelles perspectives sur plusieurs plans. C'est en effet l'occasion :
De vérifier et de mettre à niveau l'infrastructure technologique qui ne relève pas de l'informatique traditionnelle (centrale nucléaire, automatismes des installations du réseau électrique, réseau de téléphonie et de transmission de donnŽes, etc.).
1998 : Conversion et essais
La conversion des produits (systèmes informatiques, logiciels, puces intégrées, automates, automatismes et équipement informatique) ainsi que la mise à niveau de l'infrastructure technologique ont été menées à terme à la fin de 1998.
Tous les produits identifiées comme étant critiques ou gérables doivent être soumis à un processus de certification, afin de s'assurer qu'ils sont effectivement conformes à l'an 2000.
1999 : Essais intégrés et ajustement finals
L'année 1999 est consacrée à la validation de l'intégration de divers composants et aux ajustements de dernière minute. Enfin, pour parer à toute éventualité et pour plus de sécurité, Hydro-Québec entreprendra les démarches suivantes :
Le plan d'action d'Hydro-Québec pour le passage à l'an 2000 tient également compte des initiatives de ses clients et fournisseurs. Ainsi, Hydro-Québec doit s'assurer que tous ses partenaires d'affaires ont entrepris les démarches nécessaires afin de passer sans problème au prochain millénaire.
Tout fournisseur ou consultant désireux de conclure un marché avec Hydro-Québec devra démontrer que ses biens ou services respectent les nouvelles exigences de conformité au passage à l'an 2000 telles qu'elles sont indiquées dans les documents d'appels d'offres.
Enfin, dans le cadre des mesures préventives et pour s'assurer que ses clients et fournisseurs sont prêts pour l'an 2000, Hydro-Québec a rencontré les représentants des réseaux voisins, les producteurs privés qui sont branchés sur son réseau ainsi que ses quelque 250 grands clients industriels grands consommateurs d'électricité. L'entreprise participe également à deux exercices de simulation proposés par le North American Electric Reliability Council (NERC). Les résultats du premier exercice de simulation, qui a eu lieu le 9 avril dernier, sont très encourageants. Le second exercice est prévu pour le 9 septembre 1999.
Manitoba Hydro
Manitoba Hydro has given the eradication of the Year 2000 "millennium bug" the highest possible priority. Says Bob Brennan, President and CEO, "We've worked hard to ensure the continued reliability of our network in 2000, and have every confidence that Manitoba's electricity supply will be operating normally during and after the changeover to 2000."
The utility's $16-million project to make its computer and power systems Year 2000 ready began in 1996, when a multi-phase process was adopted.
An inventory was compiled of all computer systems, programs and equipment that contained date-sensitive components. All equipment with embedded calendar timing sources or micro processor chips was identified, such as systems controlling generating station units and recording meter readings, protective devices detecting transmission line faults, and fire control systems protecting equipment and people.
Over 1800 components assessed as critical to Manitoba Hydro's operation were tested and, where necessary, fixed. Only a small number did not make the date change properly. All testing and remediation of the critical hardware and software was completed by April 30, 1999, but testing will continue. Any new, repaired or replaced equipment will be re-tested and closely monitored to ensure it is working properly.
Also since 1996, Manitoba Hydro's date-driven business computer systems - such as those for billing, banking, and purchasing - were identified, analysed and tested. Systems that needed replacing or upgrading were ready February 1999.
In April, a Year 2000 readiness test was run at Limestone, Manitoba Hydro's largest and newest generating station. The clocks on all critical computers were moved forward to the year 2003 - selected since it, like 1999, precedes a leap year. The test went well, and Limestone will operate in this mode in the year 2000 to provide reassurances that the power system will survive problems.
Another reassuring component of Manitoba Hydro's operations is its new state-of-the-art, Year 2000-compliant System Control Centre that monitors and controls the provincial power system around the clock. The new facility was opened in November 1998.
Manitoba Hydro has also made contingency plans to ensure that it can recover from any unforeseen events in 2000. On December 31, 1999, for example, staff will be on site at key stations and generating facilities. Manitoba Hydro's employees are very skilled, and have proven repeatedly they can quickly restore service if it fails.
Meanwhile, because Manitoba Hydro interconnects with neighbouring utilities, it is joining with them for Year 2000 tests through the North American Electricity Reliability Council (NERC), which promotes the reliability of an electricity supply for all of North America. In April, NERC coordinated a successful continent-wide Year 2000 drill to test automated and backup communications equipment. In a worst case scenario, Manitoba Hydro can isolate its power system from interconnecting utilities should they experience problems.
As Year 2000 approaches, Manitoba Hydro is cooperating with other essential service providers in Manitoba - Manitoba Telecom Services, and the City of Winnipeg's water department and its electrical utility Winnipeg Hydro.
Within Manitoba, the utility is advising customers that no extraordinary actions will be necessary to prepare for Year 2000 from a power supply perspective. Manitoba Hydro's objective is to ensure that no disruptions to electricity service will occur on January 1, 2000 due to Year 2000 problems. It is confident this will be the case.
New Brunswick Power: Year 2000 Readiness Program
An early start on the Year 2000 challenge has given NB Power the time to prepare its systems and equipment for the transition to 2000. A detailed and extensive program to find and correct any problems which could threaten the integrity of systems is on schedule for completion in September 1999.
Preparations have focused on the testing of systems and preventative measures and on the possibilities of unforeseen problems. Keeping the public aware of these initiatives has also been a priority.
To determine which assets in generation, transmission and distribution, marketing and corporate services "would be", "could be", or "would likely not be" affected by Y2K, a system and equipment inventory was completed. A detailed analysis was conducted on each inventory item to determine whether there would be a date-related function, what would happen if the problem remained uncorrected, how critical the item was, the degree of the item's interactivity with other systems, and a resolution.
Numerous tests were conducted to determine how these items would respond to various future dates. This testing was conducted by setting the clocks on the equipment ahead, putting the equipment through its paces, and observing its behaviour. Comparisons were also made with other electric utilities and industries with similar processes and equipment.
By May 1999, testing and analysis of NB Power's systems and equipment is 99 per cent complete. Of the assessed items, 9 per cent remain to be corrected, none of which is mission critical. The program is on schedule for total Y2K readiness in September - the readiness tests have found nothing of any serious threat to the ability to generate, transmit and distribute electricity. NB Power expects to spend approximately $7 million in direct Y2K readiness activities and an additional $30 million for replacing systems which were either already obsolete and/or not Y2K compliant.
In the development of the Y2K programs, steps have also been taken to prepare for the unexpected. A business continuity plan has been designed to tackle potential problems. It has plans for additional staff on hand and on call, full operational status at all facilities, special communication equipment, preparation for manual operation and backups identified and ready. Detailed contingency plans have been drawn up and will be refined over the next few months.
Being one of the most interconnected utilities in North America, NB Power has also worked with neighbouring utilities to coordinate Y2K initiatives. This same consultation process has been utilized with suppliers of products and services.
NB Power is also participating in the North American Electric Reliability Council drills and simulated tests. On April 9, 1999, the communications drill was completed, and preparations are underway for the full North American "dress rehearsal" on September 9, 1999.
NB Power has Atlantic Canada's only nuclear generating unit. The Point Lepreau generating station has successfully met the first two critical plant systems' milestones set by the Atomic Energy Control Board. The final milestone is in June 1999 and Point Lepreau is on schedule for achieving this as well.
As part of the Y2K program, a communications initiative began in March 1999, to assure customers that NB Power is taking the Y2K issue seriously and working diligently to correct any problems. Through radio and print advertisements, customer bulletins, speaking programs, pamphlets and fact sheets, NB Power has worked to reassure customers that it is ready and prepared to respond to the potential challenges of the Year 2000.
Nova Scotia Power
At Nova Scotia Power, we have been preparing for the Year 2000 for several years.
Preparing our business for the year 2000 challenge is a priority for Nova Scotia Power. Our Year 2000 project has been underway for more than two years. A team of more than 70 employees is dedicated to preparing our business.
We have completed more than 99 per cent of the planned effort required to bring both our critical and non-critical computer systems to a state of Year 2000 readiness. We are planning to have the remainder of our computer systems in a state of Year 2000 readiness by this June.
Our major power plant systems are already operating in the Year 2000. We've proven through extensive testing that our generating units can be fully operational with the date changed to 2000. So, rather than wait for the date to arrive, we've changed the dates on the computer systems we use.
The computerized systems used in the delivery of electricity have been Year 2000 ready since March 1999.
We're working together with other utilities in North America to prepare for theYear 2000. There is a coordinated effort by the Northeast Power Coordinating Council, of which Nova Scotia Power is a member, to ensure the security of the electrical grid in northeastern North America. We are working closely with other utilities, sharing information and conducting integrated testing of our systems as part of our plans to be fully Year 2000 ready.
Ontario Power Generation
Ontario Power Generation, a successor company to Ontario Hydro, operates 80 generating stations supplying more than 85 percent of the power used in the province. Since June 1996, OPG has devoted more than $100 million to its Year 2000 program, involving the work of 340 professionals. Initially described as a potential major threat to electricity generation in Ontario, the Y2K issue continues to be a top corporate priority for OPG.
Our Year 2000 program remains on track, with all mission-critical systems certified Y2K-ready, and over 90 percent of them already in service. Plans call for all remaining systems to be in service by June 30, 1999.
In addition to these in-service deployments, there are three main thrusts to our 1999 Year 2000 Readiness program: large-scale integration testing (LSIT), developing and refining contingency plans, and preparing operationally for the event itself.
Integration and interoperability testing at thermal, hydroelectric and nuclear plants began in the fall of 1998 and has consistently produced encouraging results. Tests conducted at four thermal and seven hydroelectric stations, including the giant Niagara Falls plant are now complete. A test carried out March 26, 1999, on Unit 5 at Bruce Generating Station while the reactor was producing its rated output of 844 megawatts became the first successful large-scale integration test of a nuclear reactor in North America. Plans for the remaining LSIT's, including those at the Darlington and Pickering nuclear generating stations, are in the final stages. Despite the high reliance on computing technology in nuclear power generation, our aggressive and comprehensive program has enabled us to meet the Y2K challenge.
In April 1999, OPG participated in a North American Electric Reliability Council (NERC) industry-wide drill to assess the industry's ability to transmit critical voice and operating data even in the event of a failure of the public switched telecom network. A second industry drill, broader in scope, is scheduled for September 1999.
Day-to-day operation of Ontario's power system requires contingency plans which are able to respond effectively to a wide range of possible weather- and equipment-related disturbances. Y2K presents the additional challenge of being able to respond to events that could potentially occur simultaneously at different points in the network. For the most critical Y2K period of 1900 hours (EST) December 31, 1999 and 0400 hours (EST) January 1, 2000, we are developing a precautionary operating plan to expand our "margin of reliability" beyond its normal parameters.
To manage possible problems stemming from our dependency upon external resources, we will complete "strategic partner risk assessments" by June 30, 1999, and monitor the readiness of these organizations for the rest of 1999. If steps are needed to ensure the continuity of our operations, the contingency plan for that external resource will be activated. Because some large industrial customers may have plans to reduce their normal use of electricity over the Y2K-critical period, we are conducting a survey to determine their intentions. Although our testing has shown no indication that sudden drops in demand could create problems noticeable to customers, having advance knowledge of the intentions of our major customers will reinforce our preparedness.
Based on this extensive effort and our continued emphasis on this program for the rest of 1999, Ontario Power Generation believes there exists only a low probability of disruption to Ontario's electricity system as a result of the Year 2000 issue. Should problems occur, they should be no larger than events we already plan for, and are equipped to respond to, caused by equipment failure or severe weather.
SaskPower is Year 2000 Prepared
SaskPower is prepared for Year 2000 operations to generate and deliver electricity to the Corporation's customers throughout Saskatchewan. Our mission-critical systems are Year 2000 prepared in keeping with the North American Electric Reliability Council's (NERC) industry deadline of June 30, 1999.
Year 2000 prepared refers to SaskPower's ability to operate the Corporation's 3000-megawatt electric system. This includes power stations, switching stations, transmission and distribution lines, and the electric grid control. It also includes normal operation of "tie lines" to adjacent electric utilities, and through them, interconnection to the North American electric grid.
As of June 30, 1999, SaskPower had also prepared a working copy of a Year 2000-specific contingency plan, comprised of over 600 action plans. These contingency plans for all business and operational areas address "what if" situations and build on existing contingency plans, including system restoration, manual operation and emergency response.
SaskPower will participate in the second electric utility industry North American drill on September 9, 1999. This will be a fully operational rehearsal, including deployment of staff to important sites. SaskPower will also extensively use backup communications systems to prove the ability to manually operate power systems with skilled people at key locations. Normal power delivery to customers will not be affected.
Program Steps
A thorough date-sensitive inventory, assessment, remediation and testing process launched in 1996 has proven operations Year 2000 prepared. This work included over 15,000 embedded chips in generation and supply process control systems. Less than five percent of "mission critical" systems required changes or corrections following testing.
As a further precaution, SaskPower successfully advanced most generating unit clocks to run in Year 2000 time during 1999. This "time islanding" was essentially finished by May 31, 1999. A couple of clocks were either rolled back in time or left in real time due to equipment limitations. Clocks will be reset to real time during spring overhauls in 2000, after the 1999 to 2000 transition. Clocks were not adjusted in the transmission and distribution network, as basic functions are not date dependent.
On the generation side, SaskPower voluntarily reported one exception to NERC's June 30, 1999 deadline. This is a 60-megawatt gas turbine unit, which accounts for two percent of SaskPower's generating fleet. As part of SaskPower's long-term business plan, the unit was taken out of service in April 1999 for a major rebuild and upgrade, which includes installation of a new control system. The unit will be returned to service in September 1999.
Budget
Year 2000 Program expenditures are more reasonable than first projected. Efficiencies realized in remediation and testing will help SaskPower complete our Y2K effort within a three-year total projected cost of $12 million.
Key Milestones
As of June 30, 1999, SaskPower had achieved these Year 2000 milestones:
Dec. 31, 1998 - Complete: First draft of Operational Contingency Plan, shared with Mid-Continent Area Power Pool (MAPP)
Mar. 15, 1999 - Complete: Second draft of Operational Contingency Plan sent to MAPP
Apr. 09, 1999 - Complete: Industry-wide drill coordinated by NERC: demonstrated reliable operations using backup communications systems owned by SaskPower
May 31, 1999 - Complete: "Mission critical" systems testing and remediation 100 per cent complete
June 25, 1999 - Complete: Final copy of Operational Contingency Plan sent to MAPP
June 30, 1999 - Complete: Prepared for Year 2000 operations (embedded chip-process control systems)
June 30, 1999 - Complete: Working copy of SaskPower Contingency Plan
Sept. 09, 1999 - On schedule: Second industry-wide NERC drill: operational drill: practice of 1999 to 2000 transition
Customer and Public Dialogue
SaskPower continues to conduct an extensive program to communicate our Y2K preparedness for residential, farm, business, industrial and public needs. SaskPower is also actively sharing information with international and national industry organizations, and federal and provincial agencies.
Customer service personnel are meeting face-to-face with our large industrial and major customers to communicate our Y2K status and address issues. Working in cooperation with these customers, load expectations and needs for the 1999 to 2000 transition are being determined.
Various methods are used to update customers and the public province-wide, including meeting presentations, bill inserts, print and radio advertisements, the media, and a web site: www.saskpower.com/Year 2000.
SaskPower communications activities include a customer personal preparedness message. Communications inform that while a power outage linked to Year 2000 problems is unlikely, customers should take the same reasonable precautions they'd take for service disruptions because of storms or accidents.
Joint Utility, Interconnection and Supplier Dialogue
Saskatchewan's major providers of electricity, natural gas and telecommunications services - SaskPower, Sask-Energy and SaskTel - successfully worked together for several months to share information and develop solutions to Y2K issues and interdependencies.
Through face-to-face meetings with interconnection partners, SaskPower has found that we have equal and similar Y2K programs to all adjacent utilities. In cooperation with these partners, tie lines to Manitoba, Alberta and North Dakota will be in service during the December 31, 1999 to January 1,2000 transition.
SaskPower has also met face-to-face with critical suppliers, including coal and natural gas suppliers. These companies have detailed, extensive Y2K programs and no supply disruptions are expected. Our suppliers are committed to the delivery of essential products and services to SaskPower.
Toronto Hydro powers up for Y2K
"We're running a marathon and we have to get to the finish line before noon," says Connie Woo, Vice-President and Chief Information Officer at Toronto Hydro. "We jumped our first hurdle on March 6 when a major Y2K test went off without a glitch," says Woo. That test, known as the Manby test, was a dry run of Ontario Power Generation's ability to transmit power from its Manby transformer station to Toronto Hydro at the millennium changeover. About 200,000 Toronto Hydro customers were part of that test.
"We scaled our second hurdle on June 30 when all of our critical systems - those that affect our ability to safely deliver power to our customers and to maintain our critical business operations were tested and found ready for Y2K," says Woo.
Toronto Hydro is priming up now for its next major milestone on September 30. That's when its contingency plan on electrical distribution and business operations will be in place. The utility is basing its electrical distribution plan on the framework already in place for emergency preparedness. As an added precaution, Toronto Hydro has set a vacation embargo from December 27 to January 2 to staff the command centre and to transition information technology infrastructures and systems over the date change.
Toronto Hydro has invested $6 million to make sure its distribution system and its business systems are up and running on January 1, 2000.
In addition to customer newsletters and bill inserts, Toronto Hydro welcomes opportunities to meet with business groups, ratepayer associations and other interested parties to provide them with information about its Y2K program. Its web site has more information on Y2K at www.torontohydro.com.
TransAlta's Year 2000 Project
TransAlta is actively working to manage this global challenge as it affects the company's ability to provide customers with a safe and reliable supply of electricity. The company recognized some time ago the potential of the Year 2000 issue to cause business disruptions so it committed resources to address the issue, estimated to cost between $25 and $30 million.
Year 2000 plan
TransAlta launched its Year 2000 plan in May 1997. The project encompasses TransAlta's Canadian and international operations, including independent power projects currently under construction in Western Canada. The plan focuses on two areas: the integrity of the power system, or in some locations, electric and thermal energy services, and the integrity of business processes. The scope of the project includes automation and control systems used in power plants; transmission and distribution systems; information management and data processing systems; and facilities management systems. The steps of the project include: inventory; assessment; conversion or replacement; testing; contingency plans; and key partner preparedness.
TransAlta's progress
Plans for the remainder of 1999
TransAlta is working to the same deadline set for all electric utilities in North America to complete work on critical systems by June 30, 1999. TransAlta is on track to having critical internal devices and systems converted or replaced, where necessary, and tested by mid-1999.
Risks associated with the Year 2000 issue can be complicated because TransAlta and its customers and partners share power and exchange electronic data. TransAlta continues to co-ordinate efforts with customers and other utilities, as well as suppliers of goods and services, to assess if their business operations will affect TransAlta during critical periods. TransAlta is fine-tuning contingency plans to minimize the impact of unexpected problems that may arise within its own systems and with other parties' systems. As well, TransAlta is working with other electric utilities and regulatory bodies to co-ordinate contingency plans that address uncertainties that could affect the power system. The company will conduct training exercises to test these plans throughout the remainder of 1999.
Although the company cannot guarantee there will be no interruptions in service, TransAlta believes it is taking appropriate actions to address the Year 2000 issue. ET