Overview of Oil and Gas Services

Oil and gas services include the technologies, procedures, and support systems used in discovering, extracting, refining, and transporting petroleum and natural gas. These services are crucial for ensuring profitability, efficiency, and regulatory compliance across the entire energy supply chain. Throughout every stage of the process—from initial exploration and drilling to the final delivery of refined products—service providers play a pivotal role.

Generally speaking, the term refers to third-party companies that assist oil and gas operators. Their services often include geological surveying, drilling assistance, pipeline monitoring, infrastructure maintenance, logistics, and digital technology solutions. In most cases, these providers are experienced engineering firms or technology consultants. Therefore, they help operators reduce operational costs, boost efficiency, and modernize outdated workflows.

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Business Benefits of Oil and Gas Services

Today, the oil and gas industry faces a range of challenges, including price volatility, tightening regulations, and increasing environmental demands. As a result, companies are increasingly turning to specialized service providers to stay competitive. Instead of launching large-scale overhauls, businesses are now prioritizing targeted upgrades that encourage innovation and operational excellence.

Key benefits of oil and gas services include:

• Predictive maintenance, which reduces downtime and prevents equipment failure
• AI-powered inspections, using remote sensors to monitor wells and pipelines
• Advanced analytics, offering insights into reservoir performance and drilling efficiency
• Digital transformation initiatives, which streamline workflows and enhance agility
• Strategic M&A support, guiding effective acquisitions and partnerships

In the long run, these services enable energy producers to develop integrated strategies that provide lasting value. By tapping into external expertise, companies can better adapt to changing markets, drive innovation faster, and improve both sustainability and safety across operations.

A Battery Energy Storage System (BESS) is becoming a vital part of the evolving energy landscape. As electrification and renewable energy use expand, BESS provides a reliable power source that helps reduce emissions, lower energy costs, and strengthen the grid.

What Is BESS?

Think of BESS as a large, rechargeable battery. It stores electricity—typically generated from solar or wind—when it’s abundant. This stored energy can be used during peak demand or when grid power is disrupted.

BESS not only powers your business during high-usage periods but also serves as a dependable backup during outages. By reducing reliance on fossil fuels, it supports a cleaner, more sustainable grid.

Power Up, Pay Less

BESS stores energy when electricity prices are low, such as at night or during periods of high renewable output. That stored power can then be used during peak hours—when rates are highest—saving you money on your energy bill.

Keep Operations Running

A BESS offers reliable backup power. Whether there’s a blackout, a cloudy day, or a wind lull, it helps ensure your business stays online and productive.

Turn Surplus into Profit

Excess energy stored in your BESS doesn’t have to go to waste. You can sell it back to the grid during high-demand periods. This not only supports a greener grid but also provides an extra revenue stream.

Advanced Metering Infrastructure (AMI) has transformed utility operations. It evolved traditional meter reading into a dynamic, two-way communication system. Utilities now use AMI to remotely monitor, manage, and analyze energy usage in real time. This shift has increased grid stability, operational efficiency, energy transparency, and consumer engagement.

With AMI 1.0 widely deployed across the utility industry, attention is turning to the next phase: AMI 2.0. This evolution goes beyond a hardware upgrade. It offers enhanced functionality and deeper insights, while building on the foundation of previous investments.

However, transitioning to AMI 2.0 presents new challenges. Unlike AMI 1.0, it lacks the same level of policy-driven funding that accelerated early adoption. As a result, AMI 2.0 will likely roll out more gradually, often through hybrid systems that blend advanced and legacy infrastructure.

The true value of AMI 2.0 lies not just in smarter meters, but in the strength of its communication networks and the power of data analytics. Utilities must leverage these tools to gain real-time insights and drive operational improvements.

To prepare for this next phase, utilities should focus on scalable infrastructure and upgrading their operational technology stack. AMI 2.0 paves the way for a more flexible, efficient, and responsive grid.

Moving forward, success will depend on strategic planning, smart investment decisions, and a firm commitment to innovation. Advancing AMI is not just about adopting new technology. It’s about reimagining how utilities operate, engage with consumers, and build toward a more resilient energy future.

Distributed Energy Resources (DERs) are power-generating or energy-storage technologies that either supplement the traditional grid or offer alternative electricity sources. While most DERs use clean or renewable energy, they can operate on any primary fuel. Battery energy storage, for example, is now essential in DER systems. These batteries store excess energy and deliver it back to the grid during high-demand periods.

Some DER definitions even include technologies that help manage load fluctuations, such as smart thermostats and demand response devices. As renewable energy and decentralized power generation grow, DER availability and reliability have become critical to the modern electric utility landscape.

A few years ago, power systems depended almost entirely on large, centralized generation. These plants—powered by coal, gas, or nuclear—fed electricity through a one-directional grid. Today, that model is shifting.

Utilities are now integrating decentralized sources like solar farms, wind farms, and behind-the-meter storage systems into the power grid. These modern DERs often use two-way power flow, turning the traditional grid into a more dynamic, responsive system.

Advancements in green energy technology, grid efficiency, and cost-effectiveness are accelerating this transition. Utilities and developers are increasingly adopting DERs to improve grid stability, boost reliability, and diversify power generation.

If you work for an electric utility, you have probably seen that as power distribution technology advances, the fastest-growing DER in the sector has increased. In my experience, the following three areas have experienced the most increases:

1. Solar

Both utility-scale and behind-the-meter solar installations give utilities flexible generation options beyond traditional sources. Solar DERs help meet peak demand, support grid reliability, and provide a cleaner energy mix.

At Reesha Tech, we’ve recently worked with several utility clients to deploy solar DER connections across their service areas.

2. Wind

Wind-based DERs are gaining popularity across the U.S. These systems offer a clean, scalable, and cost-effective alternative to fossil fuel-based generation.

As more utilities seek to expand wind capacity, Reesha Tech continues to support wind DER interconnections, similar to our work with solar.

3. Microgrids

Microgrids combine multiple generation sources—such as solar and wind—into localized systems. These networks can operate independently and disconnect from the main grid during outages or high-risk events.

Though complex, microgrids provide greater energy flexibility, support grid resilience, and are growing rapidly as a subclass of DER.

What are your intentions to keep expanding distributed energy resources while bolstering system stability, dependability, and power generating variety, and how are your utilities implementing DER?

As the cost of traditional baseload generation rises and renewable energy prices fall, utilities are increasingly exploring solar and wind power. Distributed Energy Resources (DERs) are at the forefront of this shift. They offer new opportunities to enhance renewable generation and protect our environment.

By embracing new technology and applying lessons from experience, utilities can stay relevant in a rapidly evolving energy landscape. DER is not just about innovation—it’s about protecting our future.

DERs are often small in scale but large in impact. While they operate locally, their contributions to the grid are far-reaching. Most DER connections rely on solar or wind energy. Once connected to the grid, these sources become powerful assets that support environmental goals.

However, integrating DER is more complex than flipping a switch. Many developers underestimate the planning and infrastructure needed. In some cases, utilities must install new collector substations to make the connection possible. With the right strategy, DER plays a critical role in a resilient and sustainable energy future.

Power Grid Engineering (PGE) recently completed an EPC project involving three solar collector substations. We partnered with a utility and independent power producers (IPPs) who had secured contracts to supply solar energy.

Power Grid Engineering can assist our utility clients in navigating these new solar and wind power prospects because of our experience with collector substations. To ensure that DER continues to be crucial to protecting our future and yours, whether it is with centralized generation or DER in general, DER: Protecting Our Future is necessary.

Enhancing the Modern Grid for Resiliency

by Terry Nielsen:

Utilities have focused on grid modernization for more than a decade. Modern technologies can significantly enhance resilience, especially during wildfires. Strengthening the grid in the wildfire era is critical to surviving escalating environmental threats.

Utilities typically use the following strategies to build a smarter grid:

• Installing advanced or smart meters
• Establishing high-speed connectivity to support widespread use of remote sensors
• Implementing modern control center software to optimize grid performance

The goals of these upgrades include lowering costs, improving reliability, integrating more renewable energy, and enhancing customer satisfaction. However, even with these noble goals, system operators may unintentionally make trade-offs that weaken grid resiliency.

For example, PG&E has adopted a practice of shutting off power during high fire-risk conditions. While this reduces the chance of wildfires, it decreases system reliability. Additionally, when faults occur, operators often attempt to restore power automatically. If the problem is not temporary, this can result in sparks from fallen wires or dangerous fuse discharges. This approach prioritizes reliability over resilience, which can be risky in wildfire-prone areas.

Although fuse-clearing methods reduce outage time and speed up service restoration, they compromise safety. As a result, utilities must think carefully about how to manage the grid during wildfire events.

New technologies like phasor measurement units, grid optimization algorithms, low-cost sensors, and wireless fault indicators have shown promise. Many of these innovations have been funded by industry and the Department of Energy (DOE). Utilities can use them to improve grid resilience.

To do this effectively, they must upgrade distribution management systems, deploy mobile data systems, and expand sensor coverage. They should also leverage the communication networks already used for smart meters and remote monitoring.

San Diego Gas and Electric recently demonstrated a wildfire-ready system. Using smart grid tools and new sensors, they were able to detect a falling conductor and shut it off in less than a second—before it hit the ground.

In short, widespread adoption of these technologies is essential. A resilient modernized grid is no longer optional in the wildfire era. It’s a necessity for safe, sustainable, and reliable power delivery.

Strengthening Emergency Response in an Era of Climate Pressure

Utility companies are under increasing pressure from climate-related grid outages and stricter storm response regulations. As a result, utilities must strengthen their emergency response capabilities to shorten outage durations and improve customer service.

ConEdison’s Strategic Initiative with ReeshaTech

ConEdison and its subsidiary Orange & Rockland serve over 5 million customers in New York and New Jersey. To address these growing challenges, they launched a project to improve storm response management and selected ReeshaTech as their technology partner.

Evaluating and Selecting the Right Technology

At the outset, the project began with a comprehensive review of ConEdison’s Network Management System (NMS). Leveraging ConEdison’s operational insights, Reesha Tech evaluated several options and ultimately recommended Oracle Field Services (OFS). Because of its flexibility and configurability, OFS met the utility’s mutual aid objectives and proved ideal for onboarding external crews.

Streamlining Workforce Management

In addition to onboarding, OFS was leveraged to reduce the manual effort required to log time entries for contingent workers. Moreover, it replaced an aging Site Safety Management System that was nearing obsolescence, thereby improving overall operational reliability and data accuracy.

Overcoming Integration Challenges

However, the initiative posed a challenge: merging two outdated processes into one streamlined digital solution. Nevertheless, Reesha Tech collaborated closely with ConEdison to ensure that every technical and functional requirement was fully met. Through continuous coordination, the team addressed risks proactively and kept the project aligned with key milestones.

Successful Deployment and Adoption

By August 2023, the project’s first phase went live. It introduced a new mutual aid onboarding portal for creating storm events, requesting resources, and managing contractor rosters. Consequently, contractors quickly adopted the system and now submit their own rosters directly through the portal.

Advancing to Phase Two

Meanwhile, teams had already begun work on phase two, which focused on daily timesheet entry for external personnel, vehicles, and equipment. This proactive approach helped the project stay on track. In November 2024, the time entry and approval functionality officially launched, enabling more accurate post-storm billing and improved workforce tracking.

A Trusted Technology Partner

“It has been a really good experience working with ReeshaTech. Their staff has constantly shown professionalism, knowledge, and a dedication to quality. Their assistance has improved the success and efficiency of our projects. The partnership with ReeshaTech has been crucial to accomplishing our objectives and guaranteeing the accomplishment of our projects.”
— Joe Polito, Department Manager, Storm Execution & Support Operations, ConEdison

Events with adverse outcomes now pose significant risks and costs to utility operations. The range of potential threats is wide and includes hurricanes, wildfires, earthquakes, floods, extreme weather, chemical spills, and civil unrest. Demographic shifts are compounding the problem. More people now live in high-risk areas that are vulnerable to these hazards. At the same time, the costs of recovery and repair have risen sharply, making incident response more expensive than ever. For many utilities, infrequent activations of Emergency Operations Centers (EOCs) are a thing of the past. The rising frequency and severity of events now require utilities to operate continuous emergency management programs. Many utilities still rely on outdated, manual emergency management processes. These systems are often inconsistent and inefficient, limiting an organization’s ability to respond quickly and effectively. The need for digital transformation in utility emergency management has never been clearer. Modernizing these systems can significantly enhance preparedness, improve coordination, and reduce both risk and response costs. The industry is overdue for a digital-first approach.

According to the United States Environmental Protection Agency (EPA), more than 12 million distributed energy resources (DERs) currently operate on the grid. That number continues to grow. Utilities are proactively developing strategies to manage future DER expansion and capitalize on present-day opportunities. The recent FERC ruling (Order No. 2222) enables DERs to participate more easily in wholesale markets. These changes open new opportunities for the power grid, environment, and traditional utility companies.

DERs offer multiple benefits to the electric grid. Each new connection increases the system’s overall value. As more customers and devices join the network, the grid becomes stronger and more resilient than the sum of its parts. Beyond value, DERs enhance reliability by placing power generation closer to where it’s needed. This improves access to energy during peak demand and outages. When managed effectively, DERs provide local generation, energy storage, and load balancing. These features help utilities manage dynamic rates and reduce system stress. They also reduce transmission and distribution losses. This improves energy efficiency and lowers environmental impact.

According to Wood Mackenzie, solar power accounted for 37% of all new generation projects in the first half of 2020. Solar power purchase agreements also increased. By 2025, solar is expected to make up two-thirds of the U.S. DER market. The wind sector saw similar momentum during the same period. Whether deployed as DER or in centralized generation, both solar and wind allow utilities to deliver clean, reliable energy. These sources help meet customer demand and support the broader shift to renewable electricity. Together, they make a major environmental impact—especially as climate change takes center stage.

FERC Order No. 2222 allows regional transmission organizations (RTOs) and independent system operators (ISOs) to let DERs compete in wholesale energy markets. Although its full impact is still unfolding, this rule supports the shift to distributed energy. It also aims to lower costs and improve grid reliability. Utilities are using new tools to assess the cost and benefits of DERs by location, technology, and provider. Many are planning based on projected load growth and market dynamics. As DER adoption continues, utilities will explore new partnerships. They will also modernize systems to deliver cleaner, more efficient electricity.

After repeated outages and signs of structural degradation, a major utility in the Western U.S. launched a multi-year grid modernization program. The initiative aimed to improve system reliability, expand capacity, and address aging infrastructure across the service territory. As part of this effort, the project scope included upgrading 60 kV transmission lines to 120 kV. In addition, it involved rebuilding several substations to meet both current and future demands. ReeshaTech was engaged early to lead business case development, scope definition, budget forecasting, scheduling, permitting, and stakeholder coordination. Consequently, this established a strong foundation for successful execution. Our team delivered a broad range of engineering services to support the utility’s modernization goals. Specifically, on the transmission side, we managed end-to-end line design. This work included GIS mapping, topographic surveys, land acquisition, easement negotiation, rerouting plans, and final structure placement. To ensure compliance with modern standards, our engineers performed detailed pole loading analysis. These studies accounted for both communication and distribution underbuilds to guarantee safety and structural reliability. Moreover, we supported the rebuild of five substations. Our scope included specifying high-voltage equipment, switchgear, transformers, and protective relaying systems. Additionally, we handled procurement of long-lead items and ensured on-time delivery to match construction milestones. Each rebuild improved system redundancy and allowed for seamless integration with upgraded transmission lines. During construction, ReeshaTech played a critical role in execution. We coordinated with vendors and contractors, provided field engineering oversight, performed safety and compliance inspections, and managed planned outages. As a result, our integrated approach helped control costs, reduce schedule risk, and ensure high-quality results. Ultimately, the outcome was a modernized, resilient transmission network ready to support present and future load demands. This project highlights ReeshaTech’s ability to deliver turnkey utility infrastructure solutions—managing the full lifecycle from planning to energization with precision, reliability, and adaptability.