A Novel Technical Framework for Colombia’s Distribution System Operator with Distributed Energy Resources Integration

Abstract

This paper presents a thorough examination of the technical requirements for a new Distribution System Operation (DSO) scheme in Colombia. This study contextualizes these requirements to consider local particularities by looking at national and international standards and models relevant to DSO. This study aims to align the technical requirements to the DSO technologies that offer the greatest advantages (real-time data readings to automate commercial cycle, suspension and reconnection of the service, improving reliability and quality of power supply, and environmental benefits) and the fewest implementation obstacles. Today, an electrical operator can become more proactive by integrating technologies such as advanced metering infrastructure (AMI), distributed energy resources (DER), microgrids, and advanced distribution automation (ADA). This study will provide a structured framework for the implementation of a cutting-edge DSO technology in order to assist Colombia’s energy sector in becoming more dynamic and efficient with a smarter and more active electricity distribution system.

1. Introduction

The structure of electricity supply in Colombia is the result of a prolonged state intervention, which operated in a centralized manner until the reforms carried out in 1994 (Laws 142 and 143), which laid the foundations for its creation as we know it today. From the beginning of the 1990s until today, the distribution network operator (DNO) has not had to alter its role up to this point. However, the consumers’ ability to become generators and actively alter their consumption in response to market signals [1] is changing this initial conception. Furthermore, recent events like the COVID-19 pandemic, high fossil fuel prices, and climate impacts have brought to light the costs of a centralized energy system, which is mostly dependent on fossil fuels, to the global economy [2,3]. This has made the need for an energy transition even more urgent.

Traditionally, the planning and operation of the system have adopted a top-down approach, covering the one-way flow of energy from production to end users. This approach gives end users located at the end of the chain less visibility and, therefore, limits their participation in the energy transition in favor of a more flexible and sustainable system with stable prices, deferred infrastructure investment, decarbonization, and efficient demand management to avoid congestion.

The energy transition brings with it a redefinition of energy systems, an increase in the participation of new renewable energy sources, energy efficiency, and the integration of new technologies to provide more reliable and continuous services [4,5]. As a result, the current DNO will have to take a more active role in grid management by using new technologies and real-time data for monitoring, control, and operational targets. The answer to harnessing the benefits that distributed generation brings to the system is the new operator known as the Distribution System Operator (DSO).

The transition to establish a new DSO has been discussed for more than a decade. However, no model or structural design has been fully consolidated in Colombia, which is mainly due to regulatory barriers that have failed to understand the challenges faced by the industry, as well as the lack of incentives for innovation [6,7]. Even if a DSO model that takes advantage of DERs is established somewhere in the world in the coming years, the same model will not work everywhere because a unique approach independent of local particularities does not make sense [8,9,10].

This paper presents the technical requirements for the new DSO in Colombia, aligned with the standards and models widely accepted in conjunction with stakeholders [11,12,13,14,15] for the deployment of Smart Grid technologies and functions.

This paper comprises five sections. The first section covers the fundamental concepts in relation to the DSO transition; secondly, the existing standards and models for the development of Smart Grids are presented; in the third section, the technical requirements are described, divided into three categories: physical, logical components, and communication protocols. In the fourth section, the technical requirements for the conception of the DSO in Colombia are identified and discussed. Finally, the fifth section presents the conclusions and discusses future work.

The proposed research presents discussions on Smart Grid architecture, DER, and the role of the DSO, as well as their context in the Colombian energy system. This article contributes to the research as follows:

• A comprehensive analysis of the new DSO is proposed to provide the basis for an existing operator to adapt this new operating scheme.
• New technical requirements are proposed to conceive a new DSO in Colombia, classifying them into hardware, software, and communication protocols.
• Redefinition of Smart Grid standards and models to enable the integration of new technologies (AMI, BES, ADA, and DER) and functions (DER management, real-time data readings, accurate fault location, and automatic service restoration, among others) into the grid is discussed.

2. Towards a New Distribution System Operator

As DERs become more prevalent in the electric power system, the grid is changing, with an urgent need for a more active operator role in grid management [15] and operation. To benefit from a smarter and more flexible grid, conventional operators must evolve from a passive to a more active operator (DSO).

This chapter addresses the contextualization of the new DSO in two sections. The first section starts with the understanding of the DSO, its characteristics compared to the traditional model (DNO), its new responsibilities, and concludes with the global initiatives for the adoption of the DSO.

The second section describes in detail the DER, made up of those new technologies to produce and consume energy close to the consumers, which are transforming the systems as we know them.

2.1. New Distribution System Operator (DSO)

According to a document published by OATI (Open Access Technology International, Inc.: Bloomington, MN, USA), the DSO is defined as the entity responsible for the reliable operation of the distribution system (traditional role) while providing demand-side services [16]. To achieve the energy transition in the coming years, the distribution grid will have to accommodate an increasing amount of DER, allowing the operation of electricity systems to evolve from a conventional ‘rigid’ system to a flexible system at lower investment costs [15]. In this new scenario, the need for a transition from DNO to DSO becomes a necessity in order to take advantage of the benefits that distributed generation offers to the system [6]. Figure 1 shows a comparison between the conventional scenario and the emerging transition scenario.

The emergence of DERs gives the existing operator new responsibilities, including assisting the transmission system operator (TSO) with DERs, facilitating a retail market with DERs, and operating DERs to maximize grid usage and prevent congestion. However, because of bi-directional flows, which impact the protection and control devices used to manage grid variables like frequency and voltage, the large integration of DER tends to alter how systems are designed and operated [6,15].

To create a more effective, reliable, resilient, and adaptive system, planning for future networks must consider novel strategies involving currently uncommon system agents. In

Table 1. DSO-related initiatives worldwide.

Location	Country/State	Initiative	Remarks
United Kingdom	Scotland	NINES [17]	Provide an affordable and reliable energy system that takes advantage of renewable sources. Implement the necessary infrastructure for active demand management, generation, and storage.
	Great Britain	RIIO [18]	Regulatory framework that implements price controls on tariffs while incentivizing operators to innovate.
United States	New York	REV Program [19]	Adoption of DER through incentives, development of renewable sources, and microgrids. Enabling a neutral market between suppliers and consumers.
		FERC 2222 [20]	Regulation focused on enabling DERs to participate in wholesale electricity markets, thereby accelerating the energy transition.
European Union	Spain	CoordiNet [21]	Increase the efficiency and quantity of renewable energy by developing new platforms that enable interaction between different actors in the system.
		OneNet [22]	Create a replicable and scalable architecture that enables integrity in the operation of the European electricity system with a fully decentralized market.
	Sweden	CoordiNet [21]	Provide a market platform and flexible tools for DSOs to manage demand while avoiding grid infrastructure upgrades. Enable increased wind energy production through a P2P digital marketplace.
	Greece	CoordiNet [21]	Development of a local market and implementation of innovative coordination schemes that allow consumers and small actors to access the flexibility market and facilitate their active role in the management and operation of the system.

, some strategies that have emerged globally in international R&D projects in relation to the switch to DSO are listed.

2.2. Distributed Energy Resources (DER)

DER are manageable energy resources connected in distribution networks or facilities close to the end user [15]. DER includes not only generation technologies but also storage systems and controllable loads such as electric vehicles and demand response. Figure 2 shows the classification of DERs.

The following is a brief summary of each of the categories that make up DER, as shown in Figure 2.

Distributed Generation: The production of electricity near consumption centers and connected to a local distribution system, such as solar photovoltaic installations, battery storage systems, or wind turbines, is known as distributed generation, as defined by Law 1715-2014 of the Colombian regulations. Because of its close proximity to the consumer, this type of generation minimizes technical losses. Additionally, with the right control system, it can offer supplementary services to the grid during critical times. The user benefits from savings on energy bills or from the sale of surpluses to the grid; for example, in the Colombian case, the sale of surpluses is regulated by the Resolution 174-2021 where the price is equivalent to the spot price plus a component that translates into the relief of technical losses that this type of generation offers to the system.

Energy Storage: These are systems that, because of their unpredictable and uncontrollable nature, complement the production of energy from renewable sources [15]. With energy storage systems (ESS), including battery banks, pumped hydroelectric facilities (mechanical storage), hydrogen storage, and supercapacitors, among others, conservation or storage offers the grid flexibility and backup.

Demand Response: These are consumer-oriented programs that aim to enable consumers to participate actively in the network by contributing to the flexibility of the network. Demand response is considered the most versatile DER resource because it is less expensive in money and effort to intelligently influence consumers than to deploy new infrastructure and integrate it into the electrical system [23], allowing consumers to participate in an economic incentive program to connect or disconnect loads at critical times in the grid, optimizing the use of existing distribution networks and deferring new investments [24].

Electric Vehicle: It is a type of DER designed as a mobility solution that replaces the use of fossil fuels with electricity. The electric vehicle can become an active part of the system (V2G—Vehicle to Grid or V2H—Vehicle to Home) by taking and delivering energy and offering auxiliary services to the grid, such as peak demand management and energy backup, among others [25].

3. Intelligent Grid Standards and Models

Different standards and models have emerged around the world with the purpose of contributing to the understanding and development of the transformation of the sector [11,12,13,14,15]. These models and standards are not isolated concepts; they are the result of synergy among local communities, academia, and governmental entities. In fact, some standards and models are interrelated with each other with the aim of complementing each other and obtaining a more comprehensive vision.

Throughout this section, the standards and models as IEEE, NIST, SGAM, IEC, and the Colombian initiative called “Colombia Inteligente” [15], illustrated in Figure 3, are described for the design of the new DSO.

3.1. IEEE 2030 Guide for Smart Grid [11]

This guide establishes the Smart Grid Interoperability Reference Model (SGIRM), which considers the Smart Grid as a system of systems by providing a common understanding to stakeholders of the interoperability criteria from the point of view of the electricity system, communications, and information technology platforms.

SGIRM takes an approach to understanding and guiding the interoperability components of communications, power systems, and information technology platforms, becoming a key element of the Smart Grid architectural design and operation.

The IEEE 2030 guide links conceptual reference models, such as NIST and IEC, with Smart Grid applications such as AMI, plug-in electric vehicle (PEV), and others. The guide provides understanding, definitions, guidance for component design and implementation, and end-use applications for both existing and future infrastructures.

3.2. NIST Framework Release 4.0 [12]

This framework is the result of an ongoing collaborative effort involving individuals, industry organizations, academia, and government, providing invaluable feedback that helped to ensure that the work reflects a wide range of stakeholder perspectives on the issues surrounding the interoperability of the Smart Grid. Its objective is to give numerous stakeholders a high-level understanding of the system and assist smart grid stakeholders in future decision-making. Customers, markets, service providers, operations, generation including DER, transmission, and distribution are the seven domains that make up the NIST conceptual model.

3.3. SGAM (Smart Grid Architecture Model) [13]

The reference model developed by the European Smart Grid Coordination Group (SG-CG) allows not only the current state of implementations to be represented but also the evolution towards future Smart Grid scenarios.

Interoperability is a key enabler of the Smart Grid, so this feature was not an exogenous issue for the SGAM framework, which adopted an abstraction of the interoperability categories introduced by the GridWise Architecture Council (GWAC) through five layers: business goals and processes, functions, information exchange and models, communication protocols, and components.

SGAM is a three-dimensional model made up of domains (generation, transmission, distribution, DER, and customer premises), interoperability layers, and zones (process, field, station, operation, enterprise, and market). In terms of interoperability layers, SGAM provides five layers that allow the representation of entities and their relationships in the context of Smart Grid domains and information management hierarchies, taking into account interoperability aspects.

3.4. IEC 62357-1:2016 Reference Architecture [14]

The International Electrotechnical Commission (IEC) proposes a clear and comprehensive roadmap of all standards that contribute to supporting the interactions present in Smart Grids in an open and interoperable way.

The drivers of the IEC reference architecture are as follows: the need to manage increasing DERs, the need for efficient and sustainable energy, the need for secure and reliable energy to provide a resilient and cost-effective electricity system.

The IEC reference architecture is based on the domains and zones of the SGAM model to represent the information exchanges between the different elements of the Smart Grid, reflecting the possible use cases with their respective standards (IEC 57 technical committee standards and related standards).

3.5. Colombia Inteligente Initiative Architecture [15]

This is an initiative developed by a collaborative network made up of different companies and entities of the Colombian electrical sector with the purpose of promoting the integral and efficient development of intelligent systems in the infrastructure of the Colombian electrical sector.

The technological reference architecture developed by Colombia Inteligente for the integration of Smart Grids in the country is based on the reference architectures that have been developed internationally (Intelligrid, NIST, SGAM, SEPA-Gridwise, IEEE 2030, IEC 62357) and incorporates the particularities of the Colombian electrical system. The use of open architectures facilitates interoperability and streamlines implementation by meeting the requirements for consistency of equipment, scalability, interoperability, and cybersecurity.

4. Technical Requirements for the New DSO Role

This section presents the technical requirements for DSO design identified in the standards and Smart Grid models studied, based on a system-level approach (Figure 4) through the hardware (logical components), software (logical components), and communication protocols that make possible the interface between the physical and logical parts.

4.1. Physical Components

These components comprise metering devices, sensors, and devices capable of supporting the bi-directional flows and interactions existing in the Smart Grid. Within this category, we can find components such as:

• Smart meter;
• Data concentrator unit (DCU);
• Electric vehicle supply equipment (EVSE);
• DER controller;
• Power electronic converter;
• Phasor measurement unit (PMU);
• Intelligent electronic device (IED);
• Merging unit (MU);
• GPS clock;
• Recloser;
• On-load tap changer (OLTC);
• Energy storage devices;
• Information communication technology (ICT) infrastructures.

4.2. Logic Components

These comprise the set of instructions, data, or programs designed to execute specific tasks. With the digital revolution, most organizations today have incorporated software solutions into their processes to increase productivity and facilitate the use and access to information.

The following subsections describe the logical components identified in the standards and models of Smart Grids in order to know and identify the key points of each one of them at the time of their implementation.

4.2.1. Head End System (HES)

Head end systems, or HES, manage connectivity and schedule data collection from the metering infrastructure, including metering and communication devices. Additionally, they allow secure access to meters for configuration, updates, and specific requests [26].

4.2.2. Meter Data Management System (MDMS)

It is the central system of the smart metering infrastructure, which has long-term storage capacity for all data collected from the meters by the HES for further processing. The MDM is the connection point for other systems to reach the smart meters, i.e., it is a gateway to and from the HES [27].

4.2.3. Customer Information System (CIS)

A Customer Information System (CIS) contains a database of customer information. In addition to being used to store and record customer information, the CIS serves as a tool to support the organization in making decisions about customers in order to increase its competitiveness [28].

4.2.4. Distributed Energy Resources Management System (DERMS)

The DERMS is a system responsible for monitoring the DERs, which, in turn, exchange signals with the SCADA system for the operation of the distribution system. Sensors installed in the electrical network, such as PMUs, are responsible for taking information directly from the network and sending this information about the behavior of the DER to the DERMS [15].

In addition to enabling optimal management of medium and large-scale DERs, DERMS can manage the DERs connected behind the meter through a specialized set of tools, allowing it to overcome the problems caused by the high penetration of these resources and maximize the benefits delivered to the system [29].

4.2.5. Supervisory Control and Data Acquisition (SCADA)

The SCADA system allows the supervision, control, and data acquisition of the processes of generation, transmission, and distribution of energy in an electrical network.

Since the management of an electrical system is not a trivial task, the need arises to implement SCADA systems that assist operators due to the complexity of the processes involved in a power system [30]. Some of the capabilities that a SCADA system must provide are as follows:

• Ensure uninterrupted power supply in a safe environment;
• Provide real-time status of the electrical system;
• Monitor and control systems located in remote areas.

4.2.6. Advanced Distribution Management Systems (ADMS)

This system is the evolution of the distribution management system (DMS), which enables relatively advanced analysis and optimization programs and functions. An ADMS includes functions that automate outage recovery and optimize the performance of the distribution network. The following are some of the main components of an ADMS [31].

• Power distribution system monitoring.
• Decision-making and support tools.
• Power distribution system control.
• Power distribution system operational planning.
• Power distribution system engineering studies.
• Retail power market.
• Training simulator system.
• Quality control (development) system.

4.2.7. Geographic Information System (GIS)

Computer system with the ability to capture, store, analyze, and display information from assets that are spatially distributed [32]. This system is especially useful for companies in the electrical sector where the equipment that makes up the power system is generally distributed tens and hundreds of kilometers away, allowing information to be obtained quickly through catalogs or key identifier search engines, which are assigned by the company.

4.2.8. Energy Management System (EMS)

Energy management system (EMS) is a system of computer-aided tools used to perform functions such as estimation, supervision, measurement, and control of both generation and demand for a reliable and safe operation of an electrical network [33]. The operating scheme of an EMS consists of four key factors: generation, demand, storage, and control to enable the massive penetration of renewable energy.

4.3. Communication Protocols

Communication protocols comprise the set of formal rules that describe how to transmit and exchange data over a network. For utilities, due to the dynamics of their processes, it is essential that these exchanges take place in real time. This requires the development of an IT architecture that allows fast and secure data recovery.

Among the actions required for DSO deployment is the development of standards (both at the physical layer and information and communications technology levels) to improve coordination across aggregators, DSOs, TSOs, and consumers.

The main existing communication protocols for information exchange are described below.

4.3.1. IEC 61850: Communication Networks and Systems for Power Utility Automation

IEC 61850 is recognized as one of the pillars for the realization of Smart Grid goals for interoperability and device management [14]. They cover everything from basic connectivity to semantic understanding, even addressing aspects of the business context. IEC 61850 is the state of the art for communication protocols in power system automation [13]. IEC 61850 allows the DSO to deal with issues such as the integration of DER within the electrical distribution network.

4.3.2. IEC 62056: Electricity Metering Data Exchange (DLMS/COSEM)

It is a set of standards for the exchange of electrical measurement data from the International Electrotechnical Commission (IEC), mainly adopted by European countries [34]. The IEC 62056 standards are the international standard version of the DLMS/COSEM specification.

4.3.3. IEC 61400-25-2: Communications for Monitoring and Control of Wind Power Plants

The standard establishes the basis for communication between wind farms and SCADA systems, providing guidelines for establishing the wind farm information model, information exchange methods, and mapping to a standardized communications model [35].

4.3.4. IEC 60870-6: Telecontrol in Electrical Engineering and Power System Automation Applications

The IEC 60870-6 set of standards establishes guidelines for the exchange of critical time information using wide area network (WAN) or local area network (LAN) infrastructures, thus enabling the exchange of data between control centers. The standard is composed of three main parts: TASE.2/ICCP protocol and services (Inter-Control Center Protocol), functional profiling to provide services to the end system and object model.

4.3.5. IEEE 1588: Precision Time Protocol (PTP)

A standard designed to provide accurate clock synchronization in packet-based network systems. Clock synchronization can be achieved even in heterogeneous systems that include clocks with different precision and resolution [36].

4.3.6. IEEE 1815: Standard for Electric Power Systems Communications-Distributed Network Protocol (DNP3)

It is a communication protocol designed for utilities to facilitate remote communication between computer systems and equipment geographically scattered throughout the electrical system (remote station) [37].

4.3.7. IEC 61968: Application Integration at Electric Utilities System Interfaces for Distribution Management

This standard aims to facilitate the integration between applications of different distributed software application systems. IEC 61980 allows the exchange of information between EMS, DMS, and other related external computer systems [38].

4.3.8. IEC 62746: Systems Interface Between Customer Energy Management System and the Power Management System

Defines the interfaces and communication protocols that cover the chain between a Smart Grid and the Smart Home/Building/Industry area. It specifies the communication of application-level services that can incentivize the response of distributed energy resources located on the customer side, known as OpenADR [39].

4.3.9. IEC 62325: Common Information Model (CIM) for Energy Market Communication

It establishes a universal exchange mechanism for the electricity market information model, involving power generation models, physical network models, and power user models. In addition, IEC 62325 defines a message exchange mechanism that allows different applications or systems to access public data and exchange information without relying on internal subscriptions [40].

4.3.10. IEEE 1547-2018: Common Information Model (CIM) for Energy Market Communication

This standard establishes criteria and requirements for the interconnection of DER with the electric power system (EPS). The specifications and technical requirements contained in the standard are universally necessary for the interconnection and interoperability of DER [41].

5. Energy System Context and Definition of the Technical Requirements for the Design of a New DSO in Colombia

Research on DSO agrees that it must be designed for each site according to local particularities: policy, regulatory framework, distribution network conditions, among others [8]. Therefore, the following section addresses the context of the Colombian energy system, focusing on aspects such as regulation, the large integration of IT/smart technologies for grid management, and the current situation of the electricity system in the distribution operation.

5.1. The Context of the Colombian Energy System

For the electricity sector with respect to energy objectives, similar visions can be seen in the proposals of the Unidad de Planeación Minero Energética (UPME) [42] and initiatives such as Colombia Inteligente [15]. Figure 5 shows the main lines of Colombia’s strategic energy objectives:

Additionally, in Colombia, there are two areas of application of Smart Grid technologies: the National Interconnected System, or SIN for its acronym in Spanish, and the Non-Interconnected Zones, or ZNI [43]. These areas have different characteristics, which, although they may share similar functional aspects, require an adequate analysis and approach according to the particularities of each one of them.

As a result of the above, the present paper will focus on the SIN area where large-scale benefits could be achieved and later extended to the ZNI through experience and lessons learned.

As for the required architecture, it will vary depending on the Smart Grid functionalities to be deployed; therefore, it is recommended to work initially with those functionalities that contribute to the achievement of Colombia’s energy objectives and that, at the moment, have few barriers to their development. In [44], a map is shown that relates Smart Grid functionalities with Colombia’s energy objectives and the barriers to their implementation. Those functionalities with greater benefits and closer to their implementation are mainly translated into functionalities related to AMI.

5.1.1. Policy and Regulatory Context

This section presents an analysis based on the study presented by UPME [43], identifying the opportunities and barriers within Colombia’s regulatory framework for deploying Smart Grid technologies, such as AMI, ADA, and distributed energy resources–microgrids (DER-MG), of particular interest to achieve Colombia’s strategic energy objectives.

The analysis includes aspects related to AGPE and distributed generation (CREG 174 of 2021), integration of non-conventional solar photovoltaic and wind non-conventional sources (CREG 148 of 2021), integration of energy communities (CREG 101 072 of 2025), requirements for operation and management of AMI (NTC 6079-2021), and sectoral policy ICT.

Table 2. Opportunities and policy/regulatory barriers to the deployment of Smart Grid technologies in Colombia.

Technology	Policy/Regulation	Opportunities	Barriers
AMI	CREG 038-2014 [45]	Free agreement between the parties to define the ownership of the measurement system.	Stakeholders do not consider the positive externalities of smart metering deployment; instead, they focus on how and by whom the implementation costs will be recognized.
	CREG 015-2018 [46]	Methodology for the calculation of hourly charges that discriminates between different periods according to the system load level.	This feature is only available to users with smart meters.
	NTC 6079-2021 [47]	Colombian technical standard that establishes minimum requirements for the management and operation of AMI systems.	No barriers were identified in relation to the technology studied.
	Sectoral policy ICT	Protection of the privacy of information of constitutional origin. Consumption data are collected and processed with the owner’s authorization. Implementation of information security systems by the independent system operator (ISO). National policy on cybersecurity since 2011.	A Colombian Electricity Sector Computer Security Incident Response Team (CSIRT) has not been set up.
ADA	Ley 1715-2014 [48]	Promotes the implementation of non-conventional renewable energy sources, rational use of SIN energy, and DR projects.	No barriers were identified in relation to the technology studied.
	Executive Order 2492/2014 [49]	Design of mechanisms to encourage the efficient use of infrastructure and reduce service provision costs.	No barriers were identified in relation to the technology studied.
	CREG 015-2018 [46]	It encourages infrastructure modernization through incentives and compensation schemes that improve service quality.	Some features are only available to users with smart meters.
	CREG 101 019-2022 [50]	Voluntary disconnectable demand scheme as a safety ring for the reliability charge.	This feature is only available to users with smart meters.
	CREG 011-2015 [51]	DR scheme in the wholesale market under critical conditions.	This feature is only available to users with smart meters. This scheme only applies during periods of shortage.
DER-MG	Ley 1715-2014 [48]	Procedures for the connection, operation, backup, and commercialization of distributed generation. Delivery of surpluses to the grid from self-generation.	Delivery of surpluses to the grid is conditioned on the implementation of smart meters.
	CREG 174-2021 [52]	Operational and commercial aspects to enable the integration of self-generation and distributed generation.	Integration is dependent on the implementation of smart meters.
	CREG 148-2021 [53]	Connection and operation of solar photovoltaic and wind power plants with a capacity of 5 MW or more in the local distribution system.	Prior consultation with ethnic communities may be required before licences to develop projects are granted.
	CREG 101 072-2025 [54]	Operational and commercial aspects to enable the integration of energy communities.	No barriers were identified in relation to the technology studied.

below summarizes the results of the analysis with the opportunities and barriers identified within Colombia’s regulatory framework.

5.1.2. Technological Context

With regard to Smart Grid technologies, Colombia is in an initial implementation stage where most of the functionalities deployed are inherent to the technology and do not require advanced data and information processing, a scenario caused mainly by regulatory and economic barriers [55].

Deploying new Smart Grid functionalities requires incorporating new technologies and capabilities into current network operators’ processes. AMI is a catalyst technology that provides access to these new functionalities [15]. However, AMI has not yet been deployed on a significant scale in Colombia, with coverage percentages that are not significant in relation to the total number of customers served [15,55], due to the high investment required in the initial stages of deployment.

On the other hand, the infrastructure of Colombia’s distribution system offers significant technical challenges for the deployment of new technologies by operators due to its predominantly radial topology in overhead arrangement [56], which, in some cases, may be obsolete, particularly in rural areas where reliable communication infrastructure is lacking to support the real-time data flow generated by Smart Grids.

Despite the current limitations, a significant number of pilot projects focusing on AMI, DER, and ADA have been successfully deployed in Colombian cities such as Cali, Bogotá, Medellín, and Barranquilla [55], allowing technologies to be validated in different scenarios before their implementation on a large scale.

5.1.3. Current System Status and Distribution Operation

The Colombian energy matrix is mostly clean, with a good participation of conventional renewable energy (water resources), but there is still no significant participation of non-conventional resources (see Figure 6), causing the country to be exposed to high volatility in short-term energy prices (stock market) [57,58], as these are subject to weather conditions.

In addition, distribution and commercialization in Colombia are carried out by 29 operators, which are located in different regions of the country and provide an electricity service to nearly 13 million users of the SIN. In terms of distribution networks, Colombia has over 200,000 km of lines divided into over 5000 circuits, with an average of almost 100 transformers per circuit [56], which means that considerable investments are needed to achieve the adoption of Smart Grid technologies.

Regarding the infrastructure for distribution automation applications, such as remote reclosers and phasor measurement units (PMU) for network monitoring, clearing, and reconfiguration functionalities, it is observed that most operators are still in an early stage of deployment [55], which has repercussions in the area of service continuity and other technical issues [43].

In the area of continuity of energy supply, measured through the SAIDI (System Average Interruption Duration Index) indicator, characterized by measuring the time of interruptions perceived by a user, respectively, Figure 7 shows the SAIDI indicator evolution in Colombia between 2019 and 2023.

Although the efforts made by the operators have led to improvements in the quality of service over the last few years, Colombia still has much room for improvement compared to countries such as Brazil and Chile, with an average interruption of 10.4 and 13.6 h/year, respectively, given that Colombia’s average is 30 h/year.

Thus, the distribution domain is identified as the domain of the electricity sector chain where the greatest opportunities for improvement are identified. Therefore, the design of a new DSO would offer mechanisms to obtain potential results in this domain of the electricity sector.

5.2. Definition of Technical Requirements for the New DSO in Colombia

This section will define the technical requirements necessary for the design of a new DSO in Colombia in view of the integration of DERs, based on the reference architecture proposed by Colombia Inteligente [59], which has a clear vision of the system to be achieved and is also aligned with the strategic objectives of the energy sector, and on those technologies that currently have fewer barriers to their deployment and greater benefits according to the analysis carried out in the previous section (AMI, ADA, and DER-Microgrids). Similarly, as mentioned above, this study will focus on the National Interconnected System so that later, through experience and lessons learned, it can be extended to the ZNIs.

Figure 8 illustrates, in a general way, the obtaining of the technical requirements for the DSO by grouping them into three categories: physical components, logic components, and communication protocols.

Below,

Table 3. Summary of technical requirements for a new DSO in Colombia.

Technology	Physical Components	Logic Components	Communication Protocols
AMI (Advanced Metering Infrastructure)	Smart meter	Meter data management system	IEC 62056-2/62056-5-3
	Data concentrator unit
	Head end system/measurement data collector	Web access portals	IEC 61968-9/61968-100
	ICT infrastructure		ANSI C12.19/C12.21/C12.22
ADA (Advanced Distribution Automation)	Recloser	Advanced distribution management systems	IEC 61850
	Field equipment (circuit breaker, current transformer/CT, transformer, compensator)		IEC 60870
	Intelligent electronic device	Supervisory control and data acquisition/human–machine interface	IEC 62746
	GPS clock		IEEE 1588
	Merging unit	Geographic Information System	IEEE 1815
	Phasor measurement unit
	Remote terminal unit
	On-load tap changer	Customer Information System	IEEE C37.239 2010
	ICT infrastructure
DER—Microgrid (Distributed Energy Resources–Microgrid)	Controllable loads	Energy management system	IEC 61850
	Energy storage devices		IEC 62746 (Open ADR)
	DER controller	Distributed energy resources management system	IEEE 1588
			IEEE 1815
	Power electronic converter
			IEC 61400
	Electric vehicle supply equipment		IEC 60870
	Distributed generation	Web access portals	IEC 61724
	ICT infrastructure		IEC 61970

summarizes the technical requirements for the conception of the DSO in Colombia in view of the integration of the DER, based on the inputs obtained throughout the development of this work, aligned with those technologies that have fewer barriers and greater benefits in terms of their deployment.

6. Conclusions

The transition from DNO to DSO is the answer to the challenge faced by current operators to take a more active role in network management and to take advantage of the benefits that distributed generation offers to the system. This transition comes with a paradigm shift in terms of system planning and operation, giving greater visibility to the end consumer who can become an active player in the system (prosumer), contributing to a more flexible grid, thanks to its ability to generate and store energy, and to respond to market signals.

The technical requirements for DSO in Colombia were defined according to local particularities, based on national and international Smart Grid standards and models, and those technologies that have fewer barriers and greater benefits in terms of deployment. From the analysis developed in this paper on the current Colombian regulatory framework, it is identified that technologies such as AMI (advanced metering infrastructure), ADA (advanced distribution automation), and DER-Microgrids (distributed energy resources and microgrids) are technologies of particular national interest.

Most conventional grid operators are struggling to adapt to the ongoing evolution of the energy sector due to the limitations of their traditional infrastructure. Planning future networks requires innovative approaches that incorporate new and diverse system actors, aiming to build a more efficient, reliable, resilient, and flexible power system.

To accelerate this transition in Colombia, several key aspects must be addressed to evolve the traditional role of DNO to a more dynamic and proactive DSO. First, the regulatory framework must be clearly defined to establish the roles and responsibilities of DSOs. Second, promote the massification of AMI in the territory; initial investments by operators are high, and the regulation does not clearly define how these investments will be recovered. Third, data collection and exchange processes should be standardized to ensure interoperability and transparency. Finally, operators require a robust ICT infrastructure capable of supporting the complex real-time information flows of Smart Grids.

Future work will further refine the requirements for the conception of the DSO in Colombia by incorporating additional aspects such as cybersecurity, the common information model (CIM), monitoring and forecasting systems for variable generation sources, and advanced digital technologies—including artificial intelligence, the Internet of Things, digital twins, and blockchain—as well as the development of a pilot with an operator in Colombia that will allow us to put into practice the feasibility an applicability of the proposed requirements.