Master Coordinator
About the job
- A high school diploma is required.
- Zero to five years of experience is required.
- Ability to visualize and solve complex problems is required.
- Ability to apply analytical and mathematical solutions is required.
- Experience in customer service or support is required.
- Ability to obtain a thorough understanding of electricity and interconnected system operations, PJM operating and safety policies, forecasting techniques and analysis methodology, PJM Member Company operating policies, PJM markets and unit scheduling procedures, neighboring system interactions, PJM computer systems and real-time scheduling and transaction programs, NERC tagging systems, and the regional transmission tariff.
- Successful completion of the Profiles XT assessment is required.
- NERC certification at the Reliability Coordinator or Balancing and Interchange level and PJM Generation certification must be obtained within the allotted timeframe, and the employee must remain a certified NERC and PJM System Operator.
- Successful completion of the Master Coordinator computer-based final exam with a minimum score of 80% and the Operator Training Simulator hands-on examination with a minimum score of 80% is required.
- The employee must pass written and simulator tests for the Generation Dispatcher position after completing the required 12-week training period, when an on-the-job trainer is available.
- The employee must be able to work rotating shifts, including scheduled weekends, evenings, and holidays.
- Maintain power system reliability by ensuring operations comply with applicable NERC standards and PJM operating and emergency procedures.
- Operate the PJM OASIS site and provide customer support to the energy scheduling process.
- Process customer inquiries and requests for energy transactions, scheduling, and generation outage information in a timely and effective manner.
- Represent PJM as contact personnel for OASIS, TMS, EES, NERC IDC, OATI, eDart generator outages, Supplemental Status Report, Generation Checkout, and Second Pass Commitment questions.
- Direct the scheduling of generating units of PJM participants to meet PJM load and reserve requirements for future operating periods while achieving maximum system economy within established reliability criteria.
- Monitor generating-unit capability changes, return dates, operating constraints, start-up times, and minimum run times across more than 1,000 generators.
- Work with PJM Market Operations and Reliability Engineers to determine generator scheduling strategy and direct its implementation through PJM participants.
- Monitor and adjust scheduling strategy as actual system conditions change.
- Forecast and revise the PJM system load forecast for the next seven days by monitoring weather forecasts throughout the PJM service territory.
- Monitor scheduling and transaction database input for accuracy and resolve discrepancies with PJM participants.
- Maintain records and logs of pertinent scheduling and transaction information for after-the-fact analysis and reviews.
- Participate in training programs and train new Master Coordinators, familiarizing employees inside and outside the department with scheduling functions.
- Approve generating-unit maintenance outages based on projected PJM reserve situations.
- Arrange unit outage tickets and approve maintenance outage requests.
- Review participant data for correctness.
- Protect operations and maintain customer confidence by keeping information confidential.
- Handle an increasing customer-contact commitment with greater focus on customer service competencies.
- Assist in developing, evaluating, and enhancing new or existing tools, applications, and systems.
- Assist in administering PJM Transaction and Energy Markets.
- Take direct, timely real-time actions without higher-level approval, including directing the shedding of firm load to prevent or alleviate System Operating Limit or Reliability Operating Limit violations.
- Bachelor of Science in Engineering.
- Associate of Science degree in Computer Science.
- NERC Certified System Operator certification upon hire.
- PJM Operator Certifications upon hire.
On-site Position - Audubon, PA
A Master Coordinator is responsible for ensuring the PJM system is properly scheduled in accordance with PJM Market Rules and ensure that transactions in the PJM energy market are administered consistent with current rules and procedures. Additionally, s/he has the responsibility and the authority to take direct and timely real-time actions (without obtaining higher level approval) including directing shedding of firm load to prevent or alleviate System Operating Limit or Reliability Operating Limit Violations.
Master Coordinators must have a thorough understanding or the technical ability to obtain a thorough understanding of:
- The basic principles and theory of electricity and interconnected system operations, including all PJM operating and safety policies sufficient to maintain system reliability and robust markets.
- Forecasting techniques and analysis methodology.
- PJM Member Company operating policies, PJM markets, and unit scheduling procedures as well as an awareness of those of neighboring systems and their interactions with PJM.
- PJM computer systems, the real-time scheduling and transaction programs, the interrelationships of PJM Member Company and NERC tagging computer systems.
- Understanding of the regional transmission tariff by coordinating the scheduled use of transmission service and implementing curtailments as necessary.
This is a rotating shift position and requires staffing 7 x 24 including holidays. This position requires successful testing through the Profiles XT assessment and obtaining NERC/PJM Certification and other training requirements within the allotted timeframe. The Profiles XT assessment is a validated testing process that evaluates the success of system operators at PJM.
The Master Coordinator position is as an entry point for all new hires and requires advancement to the next level – Generation Dispatcher - within a specified time period. All Master Coordinators must receive training and pass tests (written and simulator) for the Generation Dispatcher position no later than whenever management determines an on-the-job trainer is available for him/her and s/he has completed the necessary 12 week training period.
Master Coordinator Training:
Training includes online training, self-study, one-on-one training, simulations, and On the Job Training (OJT). Twelve weeks of the training program consists of OJT under the supervision of an OJT trainer who guides the trainee in acquiring the knowledge and skills required for the position. Prior to being qualified as a Master Coordinator the candidate is required to successfully complete the Master Coordinator computer based final exam with a minimum score of 80%. The candidate is also required to successfully complete a hands-on examination on the Operator Training Simulator (OTS) with a minimum score of 80%.
This position requires successful testing through the Profiles XT assessment and obtaining NERC certification at the Reliability Coordinator or Balancing and Interchange level and PJM Generation certification and other training requirements within the allotted timeframe. The Profiles XT assessment is a validated testing process that evaluates the success of system operators at PJM.
Additionally, the Master Coordinator has the responsibility and the authority to take direct and timely real-time actions (without obtaining higher level approval) including directing shedding of firm load to prevent or alleviate System Operating Limit or Reliability Operating Limit Violations.
Essential Functions:
- Maintain power system reliability by ensuring operations are in compliance with applicable NERC standards and PJM operating and emergency procedures.
- Operates PJM OASIS site and provides customer support to the energy scheduling process.
- Process all customer inquiries and requests for energy transactions, scheduling, and generation outage information in a timely and effective manner.
- Represent PJM as contact personnel for the following systems: OASIS, TMS, EES, NERC IDC, OATI, eDart generator outages, Supplemental Status Report, Generation Checkout, and Second Pass Commitment questions.
- Directs the scheduling of generating units of the PJM participants to meet the PJM load and reserve requirements for future operating periods to gain maximum system economy within established PJM reliability criteria.
- Monitors generating unit (over 1000 generators) capability changes, return dates, operating constraints, start-up and minimum run times.
- Works in conjunction with PJM’s Market Operations and Reliability Engineers to determine the generator unit scheduling strategy and directs the implementation of that strategy through the PJM participants.
- Monitors and adjusts the strategy as changes on the actual system occur.
- Forecasts (and revises) the PJM system load forecast for the next seven days by monitoring weather forecasts throughout the PJM service territory.
- Monitors all input data to the scheduling and transaction database for accuracy and resolves discrepancies with the PJM participants.
- Maintains records and logs of all pertinent scheduling and transaction related information used in after-the-fact analysis and reviews.
- Participates in training programs. Serves as a trainer for new Master Coordinators and familiarizes other employees, both with dispatching and outside the department, with the scheduling functions.
- Approves unit maintenance outages of generating units based on the projected PJM reserve situations.
- Takes arrangements for unit outages (tickets) and approves all maintenance outage requests.
- Reviewing participant data for correctness.
- Maintaining customer confidence and protect operations by keeping information confidential.
- Manages an increasing customer contact commitment and therefore, a greater focus on customer service competencies
- Must be able to remain a certified NERC and PJM System Operator
- Assists in the development, evaluation and enhancements to new or existing tools, applications and systems
- Continually demonstrates flexibility in adapting to an environment of rapid change and growing complexity.
- Ability to independently handle multiple changing agendas in a quick-paced, stressful, and deadline-driven work environment.
- Assists in administration of PJM Transaction and Energy Markets.
- Requires rotating shift work (including scheduled weekends and evening periods).
Characteristics & Qualifications:
Required:
- High School Diploma
- 0-5 years of experience
- Ability to visualize and solve complex problems
- Ability to apply analytical and mathematical solutions
- Experience in customer service/support
Preferred:
- Bachelor of Science, Engineering
- AS, Computer Science
- NERC Certified System Operator Upon Hire
- PJM Operator Certifications Upon Hire
About the company
PJM Interconnection operates the largest electric grid in the United States, coordinating wholesale electricity for 67 million people across 13 states and DC to ensure power flows reliably and affordably. It evolved from a 1927 power pool to an Independent System Operator in 1997 and became a Federal Energy Regulatory Commission-designated Regional Transmission Organization in 2002, moving from coordination to market making and grid authority with bid-based trading and real-time balancing. Its distinctions include being the first ISO and first RTO, plus its large scale and shift to a first-ready, first-served model to connect new power sources and support renewable energy. The goal is to keep the lights on by balancing generation and consumption and by efficiently integrating new generators into the grid.
Company Size
501-1,000
Company Stage
N/A
Total Funding
N/A
Headquarters
Lower Providence Township, Pennsylvania
Founded
1927
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Simplify's Take
What believers are saying
- PJM's backstop auction starts Sept. 30, 2026, unlocking new capacity procurement.
- PJM's large-load registry, effective June 2027, protects existing customers from data-center cost shifts.
- DOE emergency orders let PJM run backup generators and emission-limited plants during peaks.
What critics are saying
- DOE issued PJM's seventh 2026 emergency order on Sept. 17, exposing reliability strain.
- Oklo's August 2026 FERC complaint shows PJM's interconnection process now triggers litigation.
- PJM's 6.8-gigawatt capacity shortfall and $20 billion backstop auction threaten cost backlash.
What makes PJM unique
- PJM runs 67 million customers across 13 states, the nation's largest grid operator.
- PJM's Aug. 19, 2026 strategy prioritizes AI-enabled control rooms and faster interconnection.
- PJM's July 2026 reforms created IRAS and BYONC, forcing large loads to self-supply.
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Benefits
- Hybrid Work Options
Company News
PJM, DOE declare energy grid emergency amid record-breaking warm temperatures. Due to unusually high autumn temperatures causing an increase in energy demand, PJM Interconnection, the largest energy grid operator in the United States, issued a Capacity Advisory, Maximum Generation Alert and Load Management Alert for Oct. 13. In light of this, the organization requested and received a combined emergency order from the U.S. Department of Energy (DOE) effective through Oct. 16. Usually, the rest of the year following mid-September is considered the fall shoulder period, when mild temperatures call for lower energy usage compared to peak winter and summer periods. During this time, generation and transmission owners can schedule outages for maintenance and upgrades, but due to the recently issued alerts, PJM issued a recall for these disruptions, effective at noon on Oct. 14, so that energy would still be available during this time of strain. "The conditions we have seen in both September and October reflect the reality that PJM and other grid operators are facing: increased baseload electricity demand is growing faster than new capacity can come onto the system; and unpredictable weather patterns are providing fewer days to perform important maintenance or construction on the generation and transmission equipment serving our footprint," PJM wrote in a statement to The Informer. September 2026 was the warmest recorded to date in the U.S. since 1895, averaging 69.4°F, which is 1.5°F higher than September 2025. It is the fourth month in 2026 to be the warmest on record alongside March, July and August. According to the August 2026 Market Monitor Report presented to PJM Members, average peak consumption increased by 2.2% in the first seven months of 2026 compared to the same window in 2025. "This is the new reality that grid operators are facing, but PJM is confident that our procedures, along with the DOE orders, gives us additional tools to maintain our reserve margins and allow us to operate reliably," the grid operator's statement continued. Even though announcements of an energy grid emergency could cause anxiety about potential future widespread blackouts, the measures taken by PJM and DOE have been put in place to prevent such drastic events. For example, the Capacity Advisory is the first of its kind under new emergency procedures endorsed by PJM Members in June 2026. It was implemented for times when projected and operating conditions reveal an imminent capacity shortfall, providing advance notice to Members of times when generation is anticipated to reach its maximum demand requirement. Such a procedure warns Members and distributors of maintenance outage recalls, potential decreases in imports from PJM and advises them to update information about generation availability, fuel supply concerns and environmental constraints. Similarly, the DOE 202c order permits PJM to manage these emergency conditions with more flexibility by providing temporary relief from environmental permit restrictions for generating units and, if necessary, allows the grid operator to instruct data centers and other Large Load customers to use their backup generation systems. It also authorizes PJM to use backup generation as a last resort before declaring an Energy Emergency Alert 3, which is when available supply reaches critically low levels. DOE estimates approximately 35 gigawatts of unused backup generation are available nationwide. "This order will help ensure millions of American families and businesses across the mid-Atlantic have access to affordable, reliable and secure electricity by making additional power generation, including backup power, available to use as needed," said U.S. Secretary of Energy Chris Wright. Protecting customers, calling for change. High demand on the grid, intensified by increased data center construction, is raising the supply costs for energy distributors, which affects utility prices for everyday consumers. According to the U.S. Energy Information Administration's October Short-Term Energy Outlook, wholesale prices in PJM territory are predicted to increase by 41% in 2026 compared to 2025. Households in the District saw a 7% increase in utility bill rates at the beginning of July 2026, per the Public Service Commission of the District of Columbia (DCPSC). To combat surging rates and prevent outages, corporations like Exelon have come up with incentives like the Exelon Promise to provide customers of their utilities with aid and relief. The corporation owns the following natural gas transmission and utility distribution companies: Atlantic City Electric (ACE) in southern New Jersey, Baltimore Gas and Electric (BGE), Commonwealth Edison (ComEd) in northern Illinois, Delmarva Power and Light (DPL) in Maryland's Eastern Shore and Delaware, PECO Energy Company (PECO) in southeastern Pennsylvania, and Potomac Electric Power Company (PEPCO) in Washington and parts of Maryland. "Affordability is at the beginning and end of every conversation we have," said Calvin Butler, the president and CEO of Exolon, on Sept. 17 at the Congressional Black Caucus Foundation's (CBCF) 55th Annual Legislative Conference. "Affordability can't be in the conversation by itself. It has to be affordability, reliability [and] economic development... but I know customers don't care about any of that if they can't afford to pay that bill, so it has to be an all-of-the-above approach." As part of the initiative, Exelon and its operating companies have collaborated with local non-profits to deliver $60 million in relief funding to struggling families and businesses. This fund prioritizes families who qualify for the Supplemental Nutrition Assistance Program (SNAP) and similar assistance programs. The corporation is also exploring smart battery storage solutions to help with affordability by capturing excess power and using it during peak times. It also advocates for utility-generated power to help stabilize rates and reliability over time. "In PJM, the market that we're in, we are generation short; We have a lack of supply, and anytime you have a high demand, prices go up," Butler said. "We have to do something different, and we believe utilities should be allowed to get back into the game of generation to help drive down these costs." For the time being, PJM and its collaborators are working to deal with the emergency at hand by using mitigation protocols that will keep as much energy available on the grid as possible. However, as the planet warms and causes unprecedented circumstances, experts note that innovation and collaboration are crucial to the grid's reliability and longevity. "Planned maintenance season will continue to present risks that we formerly faced only in summer and winter," PJM wrote in a statement to The Informer. "PJM is working with state and federal policymakers to address these conditions by increasing supply on multiple fronts, including speeding the connection of new electricity supply and removing state permitting barriers that are outside of PJM's jurisdiction."
Vistra (NYSE:VST) shares climb 10.7% - Here's why. October 6, 2026 Key points. * Vistra shares surged 10.7% to about $160.35 on volume more than three times the average, boosted by optimism over nuclear-power expansion. * The U.S. Department of Energy conditionally committed up to $4.2 billion to uprate and extend four Vistra nuclear plants, potentially adding 433 megawatts while reducing the company's upfront capital burden. Long-term agreements supporting AI data-center electricity demand further strengthened the growth outlook. * Analysts remain broadly positive, with a "Moderate Buy" consensus and an average price target of $217.61, but investors should weigh Vistra's high leverage and recent earnings miss against its growth prospects. * MarketBeat previews the top five stocks to own by November 1st. Vistra Corp. (NYSE:VST - Get Free Report)'s stock price was up 10.7% during trading on Tuesday. The stock traded as high as $162.69 and last traded at $160.3540. 18,000,655 shares were traded during trading, an increase of 258% from the average session volume of 5,024,565 shares. The stock had previously closed at $144.89. Vistra news summary. Here are the key news stories impacting Vistra this week: * The U.S. Department of Energy confirmed a conditional loan commitment of up to $4.2 billion for Vistra to uprate and extend the operating lives of its Perry and Davis-Besse plants in Ohio and Beaver Valley in Pennsylvania. The projects are expected to add approximately 433 megawatts of nuclear capacity while shifting much of the upfront capital burden to the federal government. * Investors see the financing as a way to improve Vistra's growth and earnings visibility without requiring as much of its own capital. The company already has long-term agreements tied to AI-related electricity demand, including a 20-year power purchase agreement with Meta and a 20-year, 207-megawatt deal with New Era Energy & Digital for a Texas data center. * A separate Google nuclear-power agreement with Constellation Energy reinforced the broader market view that hyperscalers are willing to secure decades of firm, around-the-clock nuclear power. Vistra and other nuclear generators benefited from this sector-wide repricing. * Options activity was bullish, with call-option volume rising about 52% above its typical level. Analysts remain generally constructive; BMO lowered its price target to $210 but retained an "outperform" rating. * Vistra challenged PJM's proposed resource-adequacy framework at the Federal Energy Regulatory Commission, arguing that it is discriminatory and could weaken future investment incentives. The outcome could affect regional power-market economics but is not yet resolved. * Risks remain from Vistra's high leverage and its latest quarterly miss: earnings and revenue fell well short of consensus estimates. The company's revolving-credit maturity extension improves liquidity, but debt and nuclear-operating risks remain important considerations. Wall Street analyst weigh in. Several research analysts have recently issued reports on the stock. Zacks Research downgraded shares of Vistra from a "strong-buy" rating to a "hold" rating in a report on Tuesday, August 18th. Sanford C. Bernstein restated an "outperform" rating and set a $181.00 price target on shares of Vistra in a research note on Thursday, October 1st. The Goldman Sachs Group set a $206.00 price target on Vistra in a report on Wednesday, August 12th. BNP Paribas Exane set a $255.00 price objective on Vistra in a research report on Wednesday, August 19th. Finally, Williams Trading set a $202.00 target price on Vistra in a research note on Friday. Fifteen analysts have rated the stock with a Buy rating and two have assigned a Hold rating to the company. According to MarketBeat.com, the company presently has an average rating of "Moderate Buy" and a consensus price target of $217.61. Vistra stock up 10.7%. The company has a quick ratio of 0.87, a current ratio of 0.97 and a debt-to-equity ratio of 5.87. The business has a 50-day simple moving average of $142.79 and a two-hundred day simple moving average of $151.11. The stock has a market capitalization of $53.82 billion, a P/E ratio of 27.09 and a beta of 1.38. Vistra (NYSE:VST - Get Free Report) last issued its earnings results on Friday, August 7th. The company reported $0.76 EPS for the quarter, missing the consensus estimate of $1.61 by ($0.85). Vistra had a net margin of 11.55% and a return on equity of 108.68%. The firm had revenue of $4.02 billion during the quarter, compared to analyst estimates of $5.46 billion. Equities research analysts forecast that Vistra Corp. will post 9.04 earnings per share for the current fiscal year. Vistra increases dividend. The company also recently announced a quarterly dividend, which was paid on Wednesday, September 30th. Stockholders of record on Monday, September 21st were paid a $0.23 dividend. This represents a $0.92 dividend on an annualized basis and a dividend yield of 0.6%. This is an increase from Vistra's previous quarterly dividend of $0.2290. The ex-dividend date was Monday, September 21st. Vistra's dividend payout ratio is presently 15.54%. Insider activity at Vistra. In other Vistra news, EVP Scott A. Hudson sold 44,444 shares of the business's stock in a transaction on Tuesday, September 8th. The stock was sold at an average price of $151.82, for a total value of $6,747,488.08. Following the transaction, the executive vice president owned 331,137 shares of the company's stock, valued at approximately $50,273,219.34. The trade was a 11.83% decrease in their ownership of the stock. The transaction was disclosed in a document filed with the Securities & Exchange Commission, which can be accessed through this hyperlink. The transaction was executed under a pre-arranged Rule 10b5-1 trading plan. Also, CEO James Burke bought 4,465 shares of the firm's stock in a transaction dated Tuesday, September 1st. The shares were acquired at an average price of $135.25 per share, for a total transaction of $603,891.25. Following the acquisition, the chief executive officer directly owned 1,146,352 shares of the company's stock, valued at approximately $155,044,108. The trade was a 0.39% increase in their position. Additional details regarding this purchase are available in the official SEC disclosure. 0.92% of the stock is owned by insiders. Institutional trading of Vistra. A number of hedge funds and other institutional investors have recently made changes to their positions in VST. Segra Capital Management LLC raised its holdings in shares of Vistra by 26.2% in the third quarter. Segra Capital Management LLC now owns 373,456 shares of the company's stock valued at $51,668,000 after buying an additional 77,500 shares during the last quarter. Polaris Financial Partners bought a new stake in Vistra during the 3rd quarter worth about $338,000. Versant Capital Management Inc increased its position in Vistra by 89.1% in the 3rd quarter. Versant Capital Management Inc now owns 1,023 shares of the company's stock valued at $142,000 after acquiring an additional 482 shares in the last quarter. QRG Capital Management Inc. increased its position in Vistra by 15.6% in the 2nd quarter. QRG Capital Management Inc. now owns 70,821 shares of the company's stock valued at $11,234,000 after acquiring an additional 9,556 shares in the last quarter. Finally, Envestnet Portfolio Solutions Inc. increased its position in Vistra by 19.5% in the 2nd quarter. Envestnet Portfolio Solutions Inc. now owns 1,829 shares of the company's stock valued at $290,000 after acquiring an additional 298 shares in the last quarter. 90.88% of the stock is currently owned by institutional investors and hedge funds. About Vistra. Vistra Corp. NYSE: VST is an integrated energy company headquartered in Irving, Texas. The company operates electricity generation facilities and provides electricity and related energy services to residential, commercial, and industrial customers. Its portfolio includes natural gas, nuclear, coal, solar, and battery energy storage assets. Vistra also operates a retail electricity business that offers power plans, renewable energy options, and energy-management services. Its retail brands include TXU Energy, Homefield Energy, Dynegy, and Ambit Energy, serving customers in competitive electricity markets across the United States. This instant news alert was generated by narrative science technology and financial data from MarketBeat in order to provide readers with the fastest reporting and unbiased coverage. Please send any questions or comments about this story to [email protected]. Before you consider Vistra, you'll want to hear this. MarketBeat keeps track of Wall Street's top-rated and best performing research analysts and the stocks they recommend to their clients on a daily basis. MarketBeat has identified the five stocks that top analysts are quietly whispering to their clients to buy now before the broader market catches on... and Vistra wasn't on the list. While Vistra currently has a Moderate Buy rating among analysts, top-rated analysts believe these five stocks are better buys. With the proliferation of data centers and electric vehicles, the electric grid will only get more strained. Download this report to learn how energy stocks can play a role in your portfolio as the global demand for energy continues to grow. Continue following MarketBeat
DOE issues 7th emergency grid order to PJM in 2026. The Department of Energy has handed PJM Interconnection the legal power to commandeer backup generators across the Mid-Atlantic, and it did so on 17 September 2026 with a single signature. Order 202-26-45, issued under Section 202(c) of the Federal Power Act, gives the grid operator authority to activate standby generation across its territory for a two-day window closing at the end of 18 September 2026, a measure designed to hold off uncontrolled outages during a late-summer reliability crunch. This is not a one-off. It is the seventh Section 202(c) emergency order DOE has issued to PJM in the 2026 calendar year, each triggered by the same underlying strain: demand outrunning available supply as conventional plants retire, seasonal generation fades, and new large loads keep arriving on the system. At the moment Order 202-26-45 took effect, PJM gained three specific powers it does not hold under normal market rules. It can dispatch what the order calls "Specified Resources" as needed to keep the system stable. It can activate backup generation at large industrial and commercial loads as a measure of last resort. And it can direct its Transmission Owners and Electric Distribution Companies to help carry out those instructions. PJM covers a large footprint: 13 Eastern states and Washington, D.C. The order applies across that entire region for the two-day window. The backup-generation authority can only be exercised immediately before or during an Energy Emergency Alert Level 3, PJM's highest emergency classification, the stage that sits just ahead of uncontrolled outages. PJM submitted its formal application on 16 September 2026, and DOE responded the next day. The United States has, on DOE's own estimate, more than 35 gigawatts of untapped backup generation capacity accessible nationwide. Yet during an emergency, most of it sits idle. The reason is not that the hardware fails to work. The reason is legal architecture. The standby and behind-the-meter generators at data centres, industrial plants, and large commercial sites are not enrolled in PJM's central dispatch stack. Because they are not registered as standard generation or capacity resources, PJM has no routine authority to order them to run. Then layer in environmental law: many of these units operate under state and federal air permits that limit how often they can fire. That is precisely why Section 202(c) orders bundle two things together: authority to dispatch the units and a temporary waiver of the pollution limits that would otherwise keep them off. Four distinct barriers keep this capacity out of reach under normal rules: market enrollment (units not registered in PJM's central dispatch fleet), environmental permitting (air permits cap routine operation), legal dispatch authority (PJM lacks power to compel operation without a 202(c) order), and operational hierarchy (backup use is gated to the EEA-3 last-resort threshold). The constraint on this grid is not a shortage of physical generation hardware. It is a regulatory and legal structure that keeps substantial capacity off the table until a federal emergency unlocks it. Energy Secretary Chris Wright attributed heightened late-summer grid stress to reduced solar generation as daylight hours shorten into autumn, and to the premature retirement of conventional power sources driven by prior energy policies. The solar mechanism is real and measurable: solar output in PJM falls as day length shortens through late summer and early autumn, while cooling demand can stay elevated during heat waves, creating a peak-hour mismatch that dispatchable thermal units, imports, or storage must fill. The North American Electric Reliability Corporation has previously warned that late-summer temperature surges threaten stability when dependable power sources are retired ahead of schedule. A competing diagnosis from the Center for Progressive Reform (30 June 2026) argued that the repeated emergency orders reflect under-investment in clean firm resources, transmission, and demand response, not a flaw inherent to renewable energy, and warned that PJM's emergency request "will increase air pollution." Reuters' coverage of the 30 June emergency emphasised record heat and rapid data-centre load growth as the primary operational drivers. A federal court ruling issued the same week as Order 202-26-45 struck down DOE's plant retirement authority, narrowing the legal toolkit available for managing conventional capacity exits from the PJM system. The 2026 sequence of emergency orders for PJM runs: Order 202-26-06 (26 January, sudden demand increases and generation shortages); Order 202-26-17 (early 2026, emergency generation and transmission arrangements); heat-wave orders effective 30 June to 3 July (curtailing data centres and waiving pollution limits during record heat); Order 202-26-35 (14-21 July, Specified Resources and backup generation before/during EEA-3); Order 202-26-41 (1 September, dispatch of specified units and backup generation at large loads); and Order 202-26-45 (17-18 September, the current directive). Seven Section 202(c) orders to a single grid operator in one calendar year, each telling a similar story about a system under sustained strain: retirements outrunning new dispatchable supply while demand from electrification and large industrial loads accelerates faster than capacity markets anticipated.
U.S. utilities and grid operators are urging households to prepare for tighter electricity supplies, possible rolling blackouts during extreme weather, and new risks from large loads like data centers. Kind of Ironic that Energy News Beat lost power over the holiday and had a great dry run. Hope everyone had a great Labor Day weekend. As Energy News Beat had company, a storm rolled in on Energy News Beat, and only 900 people in its county were without power. As you have heard me say, it is better to prepare and walk through a crisis calmly, and your survival rate goes up. Just went through the normal procedures, pulled 3 of the buildings off the grid, and was about to sit down and watch a movie with the family when I realized there were some missing items in my backup plans. Its guest bedroom spot was not covered in the wiring plans, and it will be fixed very easily; I already have the Jackery unit picked out. I have not spent much, as I installed one set of buildings from a Frankenstein-type system, thinking I could put my own together cheaper, but I was wrong. I really learned how to install solar by doing it all as a project, and it worked, but I highly recommend using professionals or buying a Jackery System, coupled with gasoline, natural gas, or propane systems. Generac systems are fantastic because they plug straight into natural gas or large propane tanks, but they could still go out. You don't have to spend a lot for a great system anymore. A true hybrid mix for your house is ideal. Look at the amount of power needed to run a refrigerator, a freezer, heat, and cooking. Also plan on several weeks of water. Energy News Beat all need to prepare for longer, more frequent blackouts as demand has steadily increased over the last several years. The January 2026 NERC 2025 Long-Term Reliability Assessment (LTRA) finds the overall resource adequacy outlook worsening, with 13 of 23 assessment areas facing challenges over the next decade as demand from AI data centers and other large loads outpaces planned generation and transmission. Summer peak demand is projected to rise by more than 224 GW over 10 years - 69% higher than the prior forecast - while winter demand grows even faster at 245 GW. Most near-term additions are batteries and solar PV, which are weather-dependent and inverter-based, while fossil-fired retirements continue. This mix increases winter shortfall risks. NERC classifies several regions as High Risk (shortfalls possible even under normal peaks) or Elevated Risk (shortfalls more likely in extreme conditions) starting as early as 2026-2029 in areas including parts of MISO, SPP, PJM, ERCOT, the Northwest, and Basin. The report is a risk assessment based on mid-2025 industry forecasts, not a prediction of outages. It emphasizes expediting resources, managing retirements flexibly, and coordinating on large-load growth. The July 2026 data Center event: A near-miss across multiple states. A concrete example of emerging risks occurred on July 22, 2026, in Northern Virginia's "Data Center Alley." A transmission line fault prompted clusters of data centers to automatically switch to backup power, instantly removing roughly 3-3.8 GW of demand - about 3% of PJM's load at the time. Energy News Beat has talked about this on the ENB channel. This created a sudden surplus that caused voltage and frequency swings rippling across the Eastern Interconnection. Sensors detected disturbances from Northern Virginia to Chicago, with flickering lights reported in homes. The grid stabilized in about 10-11 minutes with no cascading blackout or customer outages, but PJM initiated a synchronized reserve event. Similar but smaller events happened in 2024 and 2025. PJM (serving 13 states and 67 million people) and Dominion Energy confirmed the data centers' own protection systems triggered the transfer; the utility did not shed load. Experts called it a warning: as individual campuses approach gigawatt scale, simultaneous "ride-off" behavior can stress the grid far beyond a local fault. NERC and FERC have flagged large computational loads as a reliability concern requiring better modeling, ride-through standards, and coordination. PJM is now considering ride-through requirements so data centers stay connected during minor disturbances rather than dropping off en masse. In extreme cases, operators may curtail large loads that lack their own contracted supply to protect residential customers. Texas lawmakers already granted ERCOT similar curtailment authority over new large loads to prevent emergencies. Major utility and grid operator messages. Exelon CEO Calvin Butler, whose company serves more than 10 million customers in the Northeast and Midwest (including PJM territory), warned in June 2026 that Americans could "absolutely" face power losses as early as 2027 due to plant shortages and surging demand. He noted the region came close to curtailing hundreds of thousands of customers during recent winter peaks. PJM has projected significant capacity shortfalls and is running emergency auctions while exploring backstop measures. Edison Electric Institute (EEI) and individual utilities continue standard storm and wildfire preparedness messaging: update contact information for outage alerts, stock emergency kits, and plan for medical needs. Western utilities use Public Safety Power Shutoffs (PSPS) during high wildfire risk. In Texas, ERCOT posts seasonal updates emphasizing sufficient generation for expected conditions while reminding customers to contact local providers during outages. Texas ERCOT: lessons from winter storm Uri applied. Energy News Beat has covered this several times, and ERCOT has made substantial progress since the 2021 Uri disaster. Reforms include mandatory weatherization for generators and transmission (with thousands of inspections), firm fuel supply programs, expanded battery storage (now many times higher than in 2021), new generation, market upgrades such as Real-Time Co-optimization Plus Batteries (RTC+B) implemented in late 2025, and enhanced forecasting. Recent winter storms, including Fern in early 2026, produced far fewer forced outages than Uri despite higher peak loads. ERCOT reports high compliance on weatherization and has handled record demand without system-wide emergencies. Texas also created funding to speed reliability-focused resources and gave operators tools to manage large-load growth. Challenges remain from rapid demand increases, but the grid has proven more resilient. Practical recommendations for consumers. Utilities and emergency agencies consistently recommend household-level preparedness rather than waiting for rolling blackouts. Key steps include: Build a 72-hour (or two-week) emergency kit: one gallon of water per person per day, non-perishable food, medications, flashlights and extra batteries, a battery-powered or hand-crank NOAA radio, first-aid supplies, cash, and important documents. Keep phones charged and have backup power banks. Register medical equipment needs with your utility so they can prioritize or advise during outages. Consider backup power: portable or standby generators (keep at least 20 feet from the house, exhaust pointed away, and never run indoors to avoid carbon monoxide), whole-home battery systems (often paired with solar), or portable power stations for critical loads like refrigerators, medical devices, lighting, and communications. Prioritize essential circuits. Practice energy efficiency year-round (thermostat settings, insulation, LED lighting) to reduce strain during peaks. Know how to manually open garage doors and have an evacuation plan if an outage makes the home unsafe. In wildfire-prone areas, follow PSPS guidance and consider the benefits of covered conductors or undergrounding where utilities offer such programs. Longer-term options include community microgrids or solar-plus-storage, but start with the basics. NERC recommends that industry, regulators, and policymakers expedite the deployment of resources that provide needed reliability services, keep retirement plans flexible, and leverage large-load flexibility during periods of stress. Consumers cannot control the resource mix, but they can reduce personal risk. The grid remains reliable under most conditions, and operators have tools to manage extremes. The combination of rapid demand growth, a shifting resource mix, and events such as the July 2026 data-center trip underscores why preparation matters for 2026-2027. One thing is certain: blackouts will happen. How you prepare is how short or how badly your family will be impacted. Take note that as Iran gets more desperate, Energy News Beat has already had over 30 water companies hit by cyberattacks this year. Very interesting, and having panels that consumers could plug in and get lower bills, or charge Jackery-type units, is smart. This really hit home while I was talking with Meredeth Angwin, the Electric Grandma. She is in a retirement building with no backups, which is bringing to light a huge issue for this group of Americans. That podcast is in production and rolling through. National Emergency Securing U.S. Bulk Power Sources and Supply Chains Energy News Beat has Doomberg and the CEO of Jackery on a panel discussion on Wednesday at 9:00 Central US. Here is the YouTube Link: https://youtube.com/live/gS0fVER55EI Appendix: Sources and links. * Additional coverage of ERCOT post-Uri reforms from Power Magazine, ERCOT reports, and Texas PUC documents.
Colocation best practices for business success. Unlock the full potential of your IT infrastructure. Discover colocation best practices for reliability, scalability, and cost-efficiency. By Brilliantel Editorial Team Maximising value: data centre colocation best practices for today's enterprise. In an increasingly digital world, a robust, resilient, and scalable IT infrastructure is not just an advantage; it's a fundamental requirement for business survival and growth. As South African enterprises navigate the complexities of cloud adoption, hybrid IT, and the exponential demand for data processing fuelled by AI, the strategic decision to leverage data centre colocation becomes more critical than ever. At Brilliantel, Brilliantel understand these challenges intimately and advocate for a best-practice approach to colocation that ensures your digital backbone remains strong, secure, and future-proof. The evolving landscape of data demand. The headlines from industry leaders like Capacity Global regularly underscore the immense pressures on global digital infrastructure. The growth of AI data centres, for instance, is creating unprecedented power demands, as seen with PJM's power shortfall in the US. This highlights a universal truth: adequate power, resilient grids, and efficient cooling are paramount. For businesses in South Africa, while the scale might differ, the principles remain the same. Colocation offers a pathway to access infrastructure designed to meet these escalating demands without the prohibitive capital expenditure of building and maintaining your own facility. Why colocation now? Colocation provides businesses with dedicated space for their servers and networking equipment within a third-party data centre. This model allows enterprises to maintain ownership and control over their hardware while offloading the complexities of facility management - power, cooling, security, and connectivity - to expert providers like Brilliantel. Key benefits include: * Cost Efficiency: Reduce CAPEX and OPEX associated with data centre ownership. * Enhanced Reliability: Leverage state-of-the-art infrastructure, redundant systems, and expert management. * Scalability: Easily expand compute and storage capacity as business needs evolve. * Superior Connectivity: Access dense ecosystems of network providers, cloud on-ramps, and peering points. * Focus on Core Business: Reallocate internal resources from facility management to strategic IT initiatives. Brilliantel's best practices for successful colocation. Selecting a colocation partner is a strategic decision that demands careful consideration. Here are Brilliantel's recommended best practices to ensure your colocation strategy delivers maximum value: 1. Rigorous due diligence on facility capabilities. Don't just look at rack space. Dive deep into the data centre's foundational infrastructure: * Power and Cooling: In the age of AI and high-density computing, power stability and efficient cooling are non-negotiable. Inadequate cooling, as exemplified by the incident where municipal water caused a week of downtime for a direct-to-chip cooling loop, can be catastrophic. Ensure your chosen facility offers N+1 or 2N redundancy for power and cooling systems, and has a clear strategy for managing high-density racks and advanced cooling techniques (e.g., liquid cooling support) if your hardware demands it. * Redundancy: Evaluate the redundancy levels across all critical systems - power (UPS, generators), cooling, and network. What are their uptime SLAs? How do they achieve them? * Physical Security: Assess multi-layered security protocols, including biometric access, 24/7 surveillance, and on-site personnel. Data centre security goes beyond physical entry; it includes environmental controls and access logging. 2. Connectivity ecosystem and network agility. Colocation isn't just about housing equipment; it's about connecting it. Your provider should offer: * Carrier Neutrality: Access to multiple network service providers allows for choice, redundancy, and competitive pricing. This is crucial for optimising latency and bandwidth. * Cloud On-Ramps: Direct, high-speed connections to major cloud providers (AWS, Azure, GCP) are vital for hybrid cloud strategies. * Interconnection Services: Ability to directly peer with partners, content providers, and other businesses within the data centre ecosystem. * Global Reach: For businesses with international ambitions, consider providers with extensive fibre networks and subsea cable access. Hyperscalers like Meta investing in new subsea cables (e.g., Aurora) underline the strategic importance of global connectivity for data-intensive operations. 3. Scalability and Flexibility for future growth. Your colocation agreement should anticipate future needs: * Modular Growth: Can you easily scale up rack space, power, and connectivity as your business grows without disruptive migrations? * Contract Flexibility: Understand contract terms, renewal options, and the ability to adjust services as your requirements change. * High-Density Support: As hardware becomes more powerful, ensuring the facility can accommodate higher power per rack and advanced cooling solutions is crucial for future-proofing. 4. Operational excellence and support services. The quality of the operational team is as important as the infrastructure itself: * 24/7/365 On-site Support: Immediate response to issues can prevent minor glitches from becoming major outages. * Remote Hands Services: Expert technicians available to perform tasks like reboots, cable installations, and hardware checks, saving you time and travel. * Monitoring and Reporting: Transparent monitoring of power usage, environmental conditions, and network performance. * Compliance and Certifications: Ensure the data centre adheres to relevant industry standards and certifications (e.g., ISO 27001, PCI DSS, SOC 2) pertinent to your business's regulatory obligations. 5. Cost transparency and total cost of ownership (TCO). Look beyond the sticker price: * Detailed Pricing: Understand all components of the cost - rack space, power (kW/rack, metered, or flat rate), cross-connects, remote hands, and any additional services. * Energy Efficiency: A data centre with high Power Usage Effectiveness (PUE) indicates efficiency, which can translate to lower operational costs for you in the long run. Enquire about their energy sources and sustainability initiatives. The Brilliantel advantage. At Brilliantel, Brilliantel partner with leading data centre providers across South Africa and integrate these facilities into its robust, high-performance network. Its expertise ensures that your colocation strategy is not just about placing equipment, but about building a resilient, scalable, and cost-effective foundation for your digital future. Brilliantel guide businesses through the selection process, helping you evaluate facilities against these best practices, and providing the seamless connectivity that transforms colocation into a powerful strategic asset. Embrace the future of IT infrastructure with confidence. By adhering to these colocation best practices, South African businesses can unlock unparalleled reliability, performance, and agility, ensuring they are well-equipped to thrive in an ever-accelerating digital economy. Ready to explore how colocation can benefit your business? Contact Brilliantel today for a consultation with its experts. Data Center Colocation IT Infrastructure Business Continuity Connectivity