The Independent Electricity Market Operator of the Philippines (“IEMOP”) intends to procure/acquire the Supply, Delivery, and Installation of Servers for the Expansion of Market System Applications (Load Balancer). IEMOP now invites Suppliers/Providers to submit their Letter of Intent for the Project, addressed to Engr. Robinson P. Descanzo, President and Chief Executive Officer. Please submit the same by e-mail to BACSecretariat@iemop.ph and or by hand to the IEMOP office at 9/F Robinsons Equitable Tower, ADB Avenue, Ortigas Center, Pasig City, Philippines 1600, on or before 08 September 2026, 12:00 NN If you have questions, you can contact the Bid and Award Committee Secretariat at (02) 5318-9376.   Download Official ITB Letter Here: BAC-LOADBALANCER-ITB-26-0002

IEMOP is one of the supporting organizations for the REM™ 2026 conference. The annual Renewable Energy Markets™ (REM™) conference, taking place in Washington, D.C., on September 1–3, 2026, convenes a broad spectrum of industry professionals who are rapidly transforming the global clean energy marketplace. For more than 30 years, the REM™ conference has been a leading event for promoting and accelerating the clean energy economy. The REM™ conference brings corporate leaders, policymakers, and suppliers together to collaborate and guide the rapidly expanding market. Attendees explore emerging trends in policy, exchange best practices in renewable energy procurement and marketing, review the latest technology and market innovations, and help shape the future of renewable energy. As a supporting organization, IEMOP looks forward to being part of the conversation and contributing to the continued growth of a dynamic and sustainable energy marketplace.

Wholesale electricity prices in the Wholesale Electricity Spot Market (WESM) declined in July 2026 as improved market conditions in the Visayas and seasonally lower electricity demand helped ease market prices across the country’s three major grids. The system-wide average supply decreased to 20,587 MW, a 2.6% decline from June 2026, while average demand also dropped to 14,936 MW, or 3.4% lower than the previous month, reflecting the typical reduction in electricity consumption during the rainy season. Overall, market conditions varied across Luzon, Visayas, and Mindanao, with improvements in the Visayas contributing significantly to lower regional and system-wide prices. Despite the decrease in system-wide average supply, the improved market conditions resulted to the system-wide average market price dropping by 13.1%, from 9.54 PHP/kWh last June 2026 to 8.31 PHP/kWh in July 2026. The supply-demand conditions varied across the three regions. Supply margin in Luzon declined by 265 MW, while Visayas and Mindanao rose by 115 MW and 49 MW, respectively, influenced by outage levels, supply constraints relative to demand, the issuance of grid alert statuses, and changes in HVDC power flows. In Luzon, both average supply and average demand decreased by 3.9% and 3.3%, respectively, with the region’s average price also dropping by 8.2%, from PHP 7.95/kWh to PHP 7.30/kWh. Even with lower supply levels, several large generating units experienced forced and planned outages throughout the billing period. The highest average regional price was recorded on 7 July 2026 at 22.04 PHP/kWh. The combined unavailable capacity reached 777 MW, contributing to tighter market conditions. In Visayas, average supply slightly increased by 3.6% while the average demand declined by 4.0%. With the increased supply margin, average price decreased by 21.9%, from 14.32 PHP/kWh to 11.29 PHP/kWh. However, the slight increase in supply margin was still not enough to mitigate the nighttime peak period supply margin requirements which resulted to the continued issuance of yellow and red alerts by the System Operator (SO). The SO also declared Administered Prices on 8 July due to generation deficiencies. Despite existing system constraints, overall market conditions improved during the period as supply increased following the return of some plants from forced outage towards the latter part of this billing month. The Visayas continued to benefit from electricity imports from Luzon and Mindanao through the Leyte-Luzon and Mindanao-Visayas HVDC interconnections. During July, operating conditions on both interconnections improved, resulting in longer periods when electricity prices remained aligned across the interconnected grids. While power transfers continued to be managed to maintain the secure operation of the transmission network, improved interconnection flows enabled greater access to lower-cost generation from Luzon and Mindanao, helping reduce electricity prices in the Visayas. In Mindanao, average supply and demand decreased by 0.3% and 2.9%, respectively. Consequently, average prices dropped by 18.5%, from 12.75 PHP/kWh to 10.39 PHP/kWh. The highest average regional price was recorded on 15 July 2026 at PHP 15.19/kWh. During this period, generating units were on forced outage. The combined unavailable capacity of these units reached 474 MW, contributing to tighter market conditions. Under normal operating conditions, the Visayas grid is supported by imports from Luzon and Mindanao through the Leyte-Luzon and Mindanao-Visayas HVDC interconnections. In July 2026, the Leyte-Luzon HVDC link operated at its maximum transfer limit of 250 MW or under security-limited conditions for 40.9% of the billing period, down from 60.9% in June 2026. Similarly, the Mindanao-Visayas HVDC link operated at its maximum transfer limit of 450 MW for 26.9% compared to 39.4% in the previous month. To maintain system security and prevent overloading of the Leyte-Cebu corridor, transfers through the Leyte-Luzon HVDC link were frequently operated at security-limited levels, constraining the flow of lower-cost Luzon generation into the Visayas and contributing to price separation. Despite these constraints, improved HVDC transfer capability increased periods without price separation. For the Luzon-Visayas interconnection, unconstrained operation rose to 53.6% of the billing period in July from 31.1% in June, while the Mindanao-Visayas interconnection increased to 73.1% from 60.7%. Greater access to lower-cost generation from Luzon and Mindanao helped reduce regional prices, with Visayas LWAP declining by 21.2% to 11.29 PHP/kWh from 14.32 PHP/kWh in June. Mindanao and Luzon LWAPs also decreased to 10.39 PHP/kWh and 7.30 PHP/kWh, respectively. In July 2026, pricing interventions eased compared to the previous billing period. Administered Pricing (AP) was implemented only for 0.61% of intervals in the Visayas. Price Substitution Methodology (PSM) was applied for 17.62% (Luzon), 17.48% (Visayas), and 17.48% (Mindanao) of the intervals, due to continued manifestation of network congestion which resulted to extreme price separation. Meanwhile, Secondary Price Cap (SEC) was applied for 2.84% (Luzon), 2.73% (Visayas), and 2.91% (Mindanao) of the intervals, significantly lower than the levels observed in June 2026, indicating reduced occurrences of sustained high market prices. Overall, normal pricing conditions prevailed for approximately 74% of the billing period across all major grids, reflecting improved system conditions during July 2026. “Wholesale electricity prices declined during the July billing period, particularly in the Visayas. Consistent with seasonal demand patterns during rainy months, we are observing a decline in the system demand, while generation availability improved in parts of the Visayas, contributing to lower market prices. If current supply, demand, and transmission conditions continue, market prices may remain relatively moderate. However, actual market outcomes will continue to depend on generation availability, electricity demand, and overall system conditions.”, Engr. Isidro E. Cacho Jr., IEMOP Vice President for Trading Operations emphasized. Several generating units across all grids experienced outages throughout the month. In Luzon, forced outages across various technologies have a highest daily cumulative outage of 3,349 MW, mostly from Hydro, Coal, and Natural Gas, while planned outages across various technologies have a highest daily cumulative outage of 1,314 MW. In the Visayas, forced outages from various technologies have a highest daily cumulative outage of 975 MW, mostly from Coal and Geothermal, with 95 MW of planned outages from Geothermal. This means that Visayas relied heavily on imports from Luzon and Mindanao to meet its local demand. In Mindanao, forced outages have a highest daily cumulative outage of 743 MW, and 611 MW for planned outages from Coal and Hydro technologies. In terms of system-wide generation, renewable energy (RE) accounted for 22% of total generation in July 2026. Coal-fired generation share slightly increased from 57.9% to 59.1%. Meanwhile, Natural Gas generation declined from 18.0% to 17.0%, while Oil-based generation decreased from 2.2% to 1.4%. Solar generation increased from 6.2% to 6.9%, supported by improved daytime conditions during the billing period. Hydro generation slightly increased from 6.2% to 6.3%, while Geothermal generation decreased from 7.7% to 7.5%. Wind generation remained unchanged at 0.5%. Pumped Storage Hydro (PSH) and Battery Energy Storage Systems (BESS) remained at 0.7% and 0.2%, respectively. Energy spot market volume decreased in July 2026, accounting for 14.6% of total traded quantity from 15.1% in June 2026. Correspondingly, the total trading amount declined from 36.43 billion PHP to 28.07 billion PHP, driven by lower spot market volumes and a reduction in the Effective Spot Settlement Price (ESSP) from 11.30 PHP/kWh to 9.47 PHP/kWh. Despite the lower trading amount, bilateral contracts continued to account for the majority of transactions, representing 85.4% of total traded volume during the billing period.   Reserve/Ancillary Services Market In the reserve market, reserve prices in Luzon increased across all reserve categories. Regulation Down Reserve prices rose by 15.2%, while Regulation Up Reserve prices increased by 11.3%. These were driven by reduced offered quantities, lower reserve requirements, and higher reserve market prices despite slight reduction in spot quantities. Contingency Reserve prices posted the largest increase of 63.5%, supported by lower offered quantities, higher reserve requirements, increased spot quantities, and a higher share of reserve market procurement relative to total generation. Similarly, Dispatchable Reserve prices surged by 75.7%, resulting from increased reserve requirements, higher spot quantities, and greater reliance on reserve market transactions. Overall, the increase in reserve market prices reflects tighter reserve margins and stronger reserve market participation during the billing period. In the Visayas, reserve price movements were mixed. Regulation Down and Regulation Up Reserve prices rose by 8.4% and 14.5%, respectively, despite slightly lower offered quantities and relatively unchanged reserve requirements. The increase was primarily driven by higher reserve market contributions to total generation and increased trading activity. On the other hand, Contingency Reserve prices declined by 24.8%, largely due to a significant increase in offered quantities, higher contracted quantities, and improved scheduling adequacy, with the schedule-to-requirement ratio improving from 93% to 100%. Dispatchable Reserve prices remained nearly unchanged, decreasing marginally by 2.8%, as higher scheduled and spot quantities offset the effects of increased reserve requirements. Overall, reserve market participation increased in the region, with the reserve market share rising from 56% to 67%. In Mindanao, Regulation Reserve prices increased while Contingency and Dispatchable Reserve prices declined. Regulation Down and Regulation Up Reserve prices rose by 19.7% and 6.9%, respectively, primarily due to lower offered quantities and higher reserve market prices despite lower spot quantities. In contrast, Contingency Reserve prices decreased by 23.7% due to higher offered quantities, slightly lower reserve requirements, and reduced reserve market participation. Dispatchable Reserve prices registered the largest decline, falling by 73.9%, driven by significantly lower market transaction values and reduced spot quantities. Contracted quantities continued to account for majority of reserve procurement, representing 86% of total scheduled reserves, which helped ease reserve price movements in the region.

In June 2026, the system‑wide average supply decreased to 21,133 MW, a 1.1% decline from May 2026, while average demand decreased to 15,454 MW, or 1.9% lower than the previous billing month. Despite a reduction in both supply and demand, the system-wide average supply margin increased to 3,691 MW, compared to 3,629 MW in May 2026. The supply-demand conditions varied across the three regions. Supply margin in Luzon increased by 278 MW, while Visayas and Mindanao declined by 83 MW and 132 MW, respectively, due to higher outage levels, supply constraints relative to demand, grid alert issuances, and variations in HVDC flows. Although the overall system supply margin improved, localized supply tightness and reserve deficiencies led to the manifestation of Constraint Violation Costs (CVCs) in real-time market prices. Consequently, this led to the increase in system-wide average market price to 9.56 PHP/kWh, from 7.79 PHP/kWh last May 2026 – a 22.7% increase for June 2026. In Luzon, average supply increased by 149 MW, while average demand decreased by 234 MW. Nevertheless, the region’s average price had a 13.3% incline from 7.02 PHP/kWh to 7.95 PHP/kWh. Although supply improved, several large generating units experienced forced outages throughout the billing period, contributing to tighter market conditions and elevated prices. The billing period also recorded the highest average regional price on 29 May 2026 at 17.86 PHP/kWh. In the Visayas, average supply and demand declined by 178 MW and 12 MW, respectively, from the previous billing month. As the reduction in supply significantly exceeded the decline in demand, average prices increased by 41.7%, from 10.20 PHP/kWh to 14.46 PHP/kWh. Throughout the billing period, there were multiple issuances of yellow and red alerts, and market interventions due to generation deficiencies. The highest average regional price was recorded on 22 June 2026 at 21.68 PHP/kWh. In addition to tight energy supply conditions, recurring reserve deficiencies further contributed to higher market prices. Mindanao exhibited a similar trend to Visayas, where average supply and demand decreased by 213 MW and 55 MW, respectively. Consequently, average prices increased by 37.5%, from 9.28 PHP/kWh to 12.75 PHP/kWh. The highest average regional price was recorded on 22 June 2026 at 22.75 PHP/kWh due to outages of several large generating units. Similar to Visayas, reserve deficiencies were observed in Mindanao and contributed to higher market prices. Under normal conditions, the Visayas grid is supported by power imports from Luzon through the Leyte–Luzon HVDC interconnection. Throughout June 2026, the Leyte-Luzon HVDC facility was either operating at its maximum Luzon‑to‑Visayas transfer limit of 250 MW or at a security‑limited transfer level for 67.46% of the billing period, higher than the 46.06% observed in May 2026. Additionally, the Mindanao-Visayas HVDC flow also operated at maximum, with a transfer limit of 450 MW, for 39.36% compared to 51.84% from the previous billing period. These limitations continued to restrict the flow of lower-cost Luzon generation into the Visayas, contributing to the price separation among Luzon and Visayas-Mindanao. Several special pricing conditions were issued in the billing period. Administered Pricing (AP) tagging at 0.01% (Luzon), 7.71% (Visayas), and 0.01% (Mindanao) of the time following imposition of several market interventions due to the implementation of Manual Load Dropping. Meanwhile, Price Substitution Methodology (PSM) reached 17.71% (Luzon), 15.24% (Visayas), and 17.20% (Mindanao) of the time due to congestion and price separation, while sustained high prices resulted in Secondary Price Cap (SEC) levels of 11.10% (Luzon), 14.75% (Visayas), and 15.55% (Mindanao) of the time under the new cumulative price threshold of 12.413 PHP/kWh capped at 7.423 PHP/kWh. Several generating units across all grids experienced outages throughout the month. In Luzon, forced outages across various technologies had the highest daily cumulative outage of 3,060.5 MW, mostly from Hydro, Coal, and Natural Gas, while planned outages across various technologies had the highest daily cumulative outage of 758.30 MW. In Visayas, forced outages from various technologies have the highest daily cumulative outage of 2,295.23 MW, mostly from Coal and Geothermal, with 490.1 MW of planned outages from Geothermal. This means that Visayas relied heavily on imports from Luzon and Mindanao to meet its local demand. In Mindanao, forced outages have the highest daily cumulative outage of 1,186.70 MW, and 237.50 MW for planned outages from Hydro technology. “Grid alerts are more commonly associated with the summer months, when electricity demand is typically higher. This year, however, continued generating-unit outages and tighter regional supply conditions extended beyond the summer period, particularly in the Visayas and Mindanao. At the same time, new generating capacities are progressively entering the market, which should help support the country’s growing electricity requirements.”, Engr. Isidro E. Cacho Jr., IEMOP Vice President for Trading Operations, mentioned. Moreover, in terms of system-wide generation mix, renewable energy (RE) accounted for 21% of total generation. Coal-fired generation slightly decreased from 58.6% to 57.9%, while Natural Gas generation remained unchanged at 18%. Oil-based generation increased from 1.7% to 2.2%. Solar generation declined from 6.7% to 6.2%, while Hydro generation increased from 5.4% to 6.2%, primarily due to higher water availability brought about by the rainy season. Pumped storage hydro generation slightly decreased from 0.9% to 0.7%, while Wind generation slightly declined from 0.6% to 0.5%. For Biomass and Battery units, they remained unchanged at 1.0% and 0.2%, respectively. Energy spot market volume decreased in June 2026, accounting for 15.1% of total traded quantity from 17% in May 2026. Correspondingly, the total trading amount increased from 29.50 billion PHP to 36.57 billion PHP due to relatively higher prices. Reserves/Ancillary Services Market In the reserve market, zonal prices decreased except for Luzon’s Regulation Up and Dispatchable Reserve, Visayas’ Contingency and Dispatchable Reserve, and Mindanao’s Contingency and Dispatchable Reserve. The total system-wide reserve market transactions increased from 6.03 billion PHP in May to 6.65 billion PHP in June, largely due to increased trading amounts in Luzon, Visayas, and Mindanao. With an increase in overall energy consumption during the month, the reserve market’s Contribution Rate slightly increased from 0.56 PHP/kWh to 0.61 PHP/kWh, indicating a higher cost allocation per kWh of energy and higher reserve market transactions. In Luzon, all reserve commodities recorded higher trading amounts during the June billing period. Regulation Up and Regulation Down maintained relatively stable spot levels, while Contingency Reserve saw reduced spot exposure due to a higher ASPA share from 52% to 60%. In contrast, Dispatchable Reserve saw higher spot exposure due to a lower ASPA share from 34% to 29%. In the Visayas, an opposite trend was observed, with decreased trading on all commodities due to a decline in spot quantities from 212 MW to 149 MW. In Mindanao, all commodities recorded lower trading amounts, except for Contingency and Dispatchable reserves with maintained ASPA participation of 85%, which resulted in lower clearing prices and reduced spot exposure. “June 2026 was a volatile month for the WESM. While the country had sufficient supply overall, outages, reserve shortages, and transmission limitations created tighter conditions in some regions. Market prices reflected these conditions and showed where additional supply, reserves, and transmission capacity were most needed.”, Engr. Cacho added.