International Journal of Advanced Engineering Research and Science (IJAERS)
Vol-3, Issue-2 , Feb- 2016] ISSN: 2349-6495
Meter Data Acquisition System Implementation: (a lesson learned) Jaswinder Singh1, Gursewak Singh Brar2 1
2
M.Tech. Student , EED, Baba Banda Singh Bahadur Engineering College, Fatehgarh Sahib, Punjab, india Associate Professor, EED, Baba Banda Singh Bahadur Engineering College, Fatehgarh Sahib, Punjab, india
Abstract—This study will underline the brief the experience of the MDAS system on-going implementations process in the power distribution utilities. This research described the major areas need for better synchronization within current system and the upcoming smart grid projects. The objective of this research includes the study of current ongoing implementation under RAPDRP and investigates the challenges and lessons learned from this work. NOMENCLATURE GPRS-General Packet Radio Service IT- Information Technology RAPDRP- Restructured Accelerated Power Development and Reforms Program GIS – Geographical Information System SG – Smart Grid CMRI – Common Meter Reading Instrument AMR-Automatic Meter Reading DISCOM- Distribution Company IVRS- Interactive voice response System GSM- Global System for Mobile PSTN- Public Switched Telephone Network EDGE- Enhanced Data rates for GSM Evolution MDAS- Meter Data Acquisition System MDM- Meter Data Management ITIA- IT Implementation Agencies NBSP- Network Bandwidth Service Provider BI- Business Intelligence SRS – Software Requirement Specification CSQ- Check Signal Quality APN-Access Point Name FPGA- Field Programmable Gate Array I. INTRODUCTION The Power Sector in the country has grown manifold since independence and is most critical element in the economic growth. There is a continuous gap between the supply and demand, besides peaking shortage almost all times in a year. Despite of growth of sub-transmission and distribution sector, it could not match the investments in capacity addition. The economic growth greatly depends on a commercially viable power sector .However, the financial
www.ijaers.com
condition of the State Electricity Boards (SEB) had become a matter of concern considering that their aggregate losses had reached 26,000 crore during 2000-2001 which was equivalent to about 1.5% of GDP [1-2]. To bring the losses and make the distribution sector commercially viable, Accelerated Power Development Program (APDP) was launched in 2000-2001 as a last means [3]. Very clearly the former Accelerated Power Development and Reforms Programme has grossly under performed as it has not been able to bring down the losses to 15 per cent by the end of 2007, as originally targeted in 2000-2001. At this juncture,The Restructured- Accelerated Power Development and Reforms Programme (RAPDRP), the government’s renewed attempt to revive power sector reforms, is set to take off. The government realizing that its flagship power sector initiative with the objective of encouraging reforms, reducing aggregate technical and commercial loss and to improve the quality of supply of power. Power Ministry has appointed as the nodal agency under the aegis of the R-APDRP [4-5]. Under this scheme 54 utilities are eligible covering 1409 towns, each submitted there detail project reports and, based upon it funds has being allocated to implement the various IT solution. There are many solution provides implementing different technology under different working and administrative conditions across the country. II. RESEARCH SCOPE The research highlight the major components and challenged faced during the implementation of the substation automatic meter reading system under the RAPDRP in order to improve the condition of Rajasthan distribution companies [6-7] and the suggestion for the future similar projects. III. OVERALL SOLUTION OVERVIEW In India, there have been many initiatives taken to establish the back bone for futuristic SG. Programs like Restructured Accelerated Power Development and Reforms (RAPDRP) aim at strengthening of the distribution network through the adoption of IT technology. The meter data acquisition is one of the major modules in the scheme which account for
Page | 47
International Journal of Advanced Engineering Research and Science (IJAERS) accurate and timely information related to energy in and out flow at different electrical nodes. The MDAS module has To acquire meter data automatically from remote avoiding any human intervention.
Fig. 1: Meter Data Acquisition System • Application software for capturing, validating and analysing the Meter data. • Meter data integration with other application like energy auditing and accounting module. • MIS reports for proper planning, monitoring, decision support and taking corrective actions on the business activities by the management. • Dispatching of event notifications for faster field response and decision making. IV. PROPOSED SOLUTIONS The MDAS system has following major components (Figure: 1): • Data Concentrator Unit • Energy Meter • Meter data Management and Web Interface for visualization a. Data Concentrator Unit • National Instruments Single-Board RIO platform is off the self- product used to develop DCU along with other peripheral devices like modem and expansion cards. The sbRIO platform is compact devices that feature a real-time processor, reconfigurable FPGA, and I/O (Figure: 2) interfaces suitable for large scale deployment of the system [8].
www.ijaers.com
Vol-3, Issue-2 , Feb- 2016] ISSN: 2349-6495
following main functionalities:
Fig. 2: Figure 1: Single-Board RIO • SBRIO is used as main controller and processing unit to acquire the data from the network of meters. The program developed using LabVIEW access the resources of modem for GPRS[9-11] communication programmatically in the application. • The program was developed to interact with the meter over RS 485 communication and execute the DLMS command over serial interface to read the data from various meter (Figure: 3). • The DCU send the command in sequence to each meter and retrieve the data i.e. instantaneously and load survey. • The DCU made the connection with the static IP provide at the server and transmit the data to control centre.
Fig. 3: LabVIEW b. Energy meter • The substation are having 3phase four wire A.C HV Trivector energy meter with RS 485 ports, and are DLMS/COSEM/IEC-62056 compliance.DLMS[12] standard has been adopted to solve the interoperability issue of different make / model. • The meters installed in the substation are connected in the multidrop configuration, to create the network of the meters.
Page | 48
International Journal of Advanced Engineering Research and Science (IJAERS)
Fig. 4: User Interface c. Meter Data Management Utility Control center has the front end communication server enabled with IP, which is used to receive the data from the remote substation. Multiple clients can view the application, according to the granted access (Figure: 4).The application enables the remote configuration of DCU and provides relevant information at various decision making levels in a timely and accurate manner. Data validation, estimation and editing (VEE) is a process that identifies problematic data that comes from meter data collection systems before it reaches other utility systems and provides tools for addressing quality issues according to a utility’s specific best practice rules and meter-specific parameters. V.
IMPLEMENTATION LESSONS LEANED
•
MDAS implementation has faced challenges mainly due to insufficient time allocated and technical capability of the utilities. • Lack of clarity of the scope of work leads to unnecessary confrontation and delays for large scale deployment. • Insufficient staff allocation by the utility for installation and coordination, lack of ownership and involvement by all stakeholders at operational level and project planning process. • Items under complete control of the utility are often found to not be ready, it has been noticed on many sites that the AMR compatible meters are not installed and site representative is not aware about the program. • Successful DCU installation depended on timely execution of the GIS field survey. At many places DCU were installed prior to GIS field survey, which resulted in incorrect mapping of base data. • Utility personnel should be trained to configure and install DCU, or this activity should be carried out jointly for successful changes in the field. 5.1 Meter Lessons The main data point for MDAS are the energy meter installed in the substations on incoming and outgoing feeders, there are many points to consider regarding integration, installation and replacement
www.ijaers.com
Vol-3, Issue-2 , Feb- 2016] ISSN: 2349-6495
• Data communication port of the meters was not working at many locations due to exposure to the environment. Meter shall be protected in IP65 enclosure for outdoor location. • It is better that installation of only one or two makes of meters should be encouraged rather than installation of many different makes of meters in the field. • DCU communication cable was removed during new meter installation without informing the data centre. 5.2 Communication Network Lessons Learned Connectivity to data center is the backbone of the MDAS , GPRS is widely adopted , as it is economically mean of data transmission . • If a DCU has failed in data transfer for two/three consecutive days, the team has to physically inspect the location, carry out the in-depth analysis and follow up constantly with GPRS service provider, so that the problem is rectified. • Static and Dynamic IP schemes both are used in different states and there is no specific recommendation envisaged in this context. It is therefore suggested that Utility and ITIA may jointly decide which scheme is giving better result in the jurisdiction of respective GPRS Service Provider. • Regarding other field issues, there should be regular field visits and physical inspection for unavailable meter data, identification of faulty component and taking corrective action by Utility (for Meter) and ITIA (for DCU and connectivity) till the problem is addressed and solved. • There should be mechanism to insist respective GPRS Service provider for Regular Network Audit maintain the Quality of Service for effective data transfer • GPRS Link Monitoring for Availability & Performance by ITIA and NBSP will ensure better Data Communication and planned and unplanned outages should be shared by GPRS Service provider with ITIA/Utility. • In order to successful transfer the data minimum signal strength of 18 CSQ (equivalent to -77 dbm) is required. Weak signal strength and inconsistency at many locations across vast areas impacted successful reading cycles. 5.3 Firmware and Software Lessons Learned • This specification is overlapping the MDM/BI applications/systems. Considering future smart grid scalability needs of MDAS, any such overlapping specification should be excluded from the MDAS, and should be part of the MDM/BI applications/system.
Page | 49
International Journal of Advanced Engineering Research and Science (IJAERS) •
For future Smart Grid support, Asset monitoring should be a separate application outside the context of MDAS. The Asset management system should interact with MDAS using standardised interfaces. • The Meter Data Acquisition Software System (MDAS) hosted at Data Center should be configured in such a manner that daily Load Survey Data Transfer between DCU and Data Acquisition Server (at data Center) should preferably happen during off-peak hours at night between 00-00 to 05-00 Hours and should be done in a staggered manner 5.4 Implementation Lessons Learned • The management team must consist of one experienced individual, working closely with supplier and field maintenance personnel for accessing meter and for maintenance procedures. • Prior to the project’s implementation, the MDAS team and senior management had to determine the preinstallation, installation and post-installation responsibilities along with the utilities • Proper planning and Administrative restructuring in the Utilities for migration to new IT based business environment – preparing for change management. • Parallel action need to be plan for accelerating implementation, development of software, adoption of best practices for MDAS activities. • Identifying critical areas and focusing on the same. • The experimental design allows sufficient enrollment sample size to do statistical analysis on the load impacts, as well as provide a fairly clear understanding of reliability and operational issues. 5.5 Operational Lessons Learned • Field implementation issues have been found to be a major contributor of meter data unavailability at Data center. The problem originates mainly due to faulty meters, meter connectivity with electrical system, and with DCU. • The wires are not handled properly by the technician in the switch yard, any often cut during civil work. • The DCU communication wiring is not done properly using best practices, and moreover there no standard guideline mentioned in the requirement. • Problems with connectivity could be solved by having a push function on the data from the DCU so that data could be sent during less congested times. • The operations team will become the core of the future operations center, and their capabilities and skills will influence the long-term success of MDAS. • Deployment of dedicated and skilled manpower by utilities and ITIA, for MDAS, and Software Development.
www.ijaers.com
Vol-3, Issue-2 , Feb- 2016] ISSN: 2349-6495
•
Disconnection of network services due to nonpayment of data usage bills. The meters at substation are read in real time, which leads to higher data usage and increases the monthly bills (GPRS charges) for utilities. • In some cases the SIMs provided were configured to a public APN (not barred from using the internet) rather than a private APN (barred from using the internet) resulting in misuse of the SIM and consequently high bills. 5.6 Integration Lessons Learned • The manual option should be eliminated; the specification should focus on remote tools that enable the user to automatically configure the DCU. • The MDAS should have mechanism to export the Network Topology via standard protocols/interfaces to a Network Management System. • The methodology of Validation, Estimation and Editing (VEE) – is repeatedly undergoing changes and this methodology is not consistent across DISCOM/Utilities. The VEE methodology should be standardised. • Once standard VEE methodology is done, it is possible to start evaluating system performance and effectiveness. • Both time set and time Sync functionality needs to be included so that appropriate method can be used. 1mS resolution may not be required for meters. • Energy Audit component/subsystem should have clearly defined standard interfaces to other subsystems (MDAS and MDM, etc.) to orchestrate Energy Audit application. • Software integration is an area that is still evolving for MDAS, and there are many issues to consider. Some standard approach needs to follow for data integration IEC CIM, Multispeak, or utility define standards[1315]. • There are certain aspects of system integration and scalability, which at some point will require integration of the new technology into existing production systems, will encounter other types of delays due to these additional systems integration requirements. • Business Process automation and integration with legacy system taking longer time. 5.7 Capacity Building • The utility has requires to transfer the operating knowledge from the vendor to in-house staff. They were engaged in the traditional knowledge-transfer approaches, such as training and hands-on experience. Although this process was somewhat time intensive, it established a strong sense of accountability and Page | 50
International Journal of Advanced Engineering Research and Science (IJAERS)
• •
ownership, and proved to be an effective knowledgetransfer tool MDAS data hold potential for load forecasting on feeder or substation level. ITIA to enlarge man power with domain knowledge in power sector, Utility to augment core team dedicated for the implementation.
Vol-3, Issue-2 , Feb- 2016] ISSN: 2349-6495 Catalunya (UPC) Address: Jordi Girona 1-3, Mòdul C3, 08034 Barcelona, SPAIN. [13] http://www.dlms.com/ [14] http://www.iec.ch/ [15] http://www.dmtf.org/standards/cim [16] http://www.multispeak.org/
VI. Conclusion India has to go long way to accelerate the reforms in distribution sector. There are several lessons leant from the RAPDRP –MDAS project in terms planning, operation, implementation and capacity building. The technology show measurable operational savings from automation meter reading system, and the data recorded provides accurate and on time energy audit and accounting reports. Further the data can be used for advance application line load forecasting and management, power quality analysis This implementation of MDAS has provided hand for experience to all the stakeholders for future smart grid project. REFERENCE [1] Central Electricity Authority ( CEA) [2] Power Finance Corporation ( PFC) [3] APDP http://www.indianelectricity.com/ [4] RAPDRP, Ministry of Power, Government of India. Source: http://www.apdrp.gov.in/ [5] http://www.apdrp.gov.in/Forms/Know_More.aspx [6] Technical Report, All India Electricity Statistics (2007-08): General Review 2009, May 2009, Central Electricity Authority, Ministry of Power, Government of India. Source: http://www.cea.nic.in/publication.html [7] Ministry of Power, Govt. of India – 2009-10 3. [8] JVVNL, Jaipur, Rajasthan – 2009-10 4. ITIA, RAPDRP – 2010 [9] National Instruments http://www.ni.com [10] Liu Zhong-Xuan, Jiang Xiao-Yu, Han Zhao-fu, Zong Yan-Tao, Du Meng, “Research on remote wireless monitoring system based on GPRS and MCU”, International Conference on Electric Information and Control Engineering (ICEICE-2011), 2011, pp. 25042506. [11] Chih-Hung Wu; Shun-Chien Chang; Yu-Wei Huang, "Design of a wireless ARM-based automatic meter reading and control system,” Power Engineering Society General Meeting, 2004. 6-10 June 2004 Page(s):957 - 962 Vol.1 [12] Overview and Capacity of the GPRS (General Packet Radio Service) 1Carles Ferrer, Miquel Oliver Applied Maths & Telematics, Universitat Politècnica de
www.ijaers.com
Page | 51