Natural gas rose to 3.36 USD/MMBtu on July 11, 2025, up 0.58% from the previous day. Over the past month, Natural gas's price has fallen 3.89%, but it is still 44.10% higher than a year ago, according to trading on a contract for difference (CFD) that tracks the benchmark market for this commodity. Natural gas - values, historical data, forecasts and news - updated on July of 2025.

Natural gas prices are the highest in the residential sector. In 2023, U.S. households paid an all time high average of 15.2 U.S. dollars per 1,000 cubic feet. Commercial natural gas costs were second-highest, while prices in the electric power sector were the lowest, at around four U.S. dollars on average. Prices for the industrial and electric power customers tend to be close to the wholesale electricity price. All sectors saw a year-on-year increase in natural gas prices in 2022 due to the decline in U.S. natural gas production in the first quarter of 2022, which resulted in high withdrawals of natural gas from storage and an increase in average natural gas prices. The growing natural gas market In recent years, the average natural gas prices for all sectors have been increasing in the United States. In 2022, the residential sector witnessed an increase in natural gas prices higher than 2008, while natural gas prices for other sectors were still lower despite increases in average natural gas prices for those sectors. Meanwhile, consumption of natural gas has increased more than any other fuel type following the 2008 Recession. Petroleum consumption has been more variable, and use of coal has significantly decreased. The price of coal and crude oil had already been increasing since the early 2000s, and was further exacerbated by the financial crisis. Around the same time, the cost of natural gas dropped significantly, making it a more viable economic alternative compared to other fossil fuels. This decrease was in part the result of drastically increased production of shale gas as a result of hydraulic fracturing and other techniques.

In 2024, the price of natural gas in Europe reached 11 constant U.S. dollars per million British thermal units, compared with 2.2 U.S. dollars in the U.S. This was a notable decrease compared to the previous year, which had seen a steep increase in prices due to an energy supply shortage exacerbated by the Russia-Ukraine war. Since 1980, natural gas prices have typically been higher in Europe than in the United States and are expected to remain so for the coming two years. This is due to the U.S. being a significantly larger natural gas producer than Europe. What is natural gas and why is it gaining ground in the energy market? Natural gas is commonly burned in power plants with combustion turbines that generate electricity or used as a heating fuel. Given the fact that the world’s energy demand continues to grow, natural gas was seen by some industry leaders as an acceptable "bridge-fuel" to overcome the use of more emission-intensive energy sources such as coal. Subsequently, natural gas has become the main fuel for electricity generation in the U.S., while the global gas power generation share has reached over 22 percent. How domestic production shapes U.S. natural gas prices The combination of hydraulic fracturing (“fracking”) and horizontal drilling can be regarded as one of the oil and gas industry’s biggest breakthroughs in decades, with the U.S. being the largest beneficiary. This technology has helped the industry release unprecedented quantities of gas from deposits, mainly shale and tar sands that were previously thought either inaccessible or uneconomic. It is forecast that U.S. shale gas production could reach 36 trillion cubic feet in 2050, up from 1.77 trillion cubic feet in 2000.

UK Gas rose to 85.31 GBp/thm on July 11, 2025, up 1.32% from the previous day. Over the past month, UK Gas's price has fallen 0.15%, but it is still 17.29% higher than a year ago, according to trading on a contract for difference (CFD) that tracks the benchmark market for this commodity. UK Natural Gas - values, historical data, forecasts and news - updated on July of 2025.

The state with the highest price of natural gas for industry in 2023 was Hawaii, standing at 28.4 U.S. dollars per thousand cubic feet, a decrease when compared to the previous year. During the same year, Texas had the lowest industrial natural gas price in the country, at 2.7 U.S. dollars per thousand cubic feet. Meanwhile, the average natural gas price for industry in the U.S. stood at 7.9 U.S. dollars per thousand cubic feet in 2022.

The average monthly price for natural gas in the United States amounted to **** nominal U.S. dollars per million British thermal units (Btu) in May 2025. By contrast, natural gas prices in Europe were about three times higher than those in the U.S. Prices in Europe tend to be notably higher than those in the U.S. as the latter benefits from being a major hydrocarbon producer. Europe's import reliance European prices for natural gas rose most notable throughout the second half of 2021 and much of 2022, peaking at over ** U.S. dollars per million Btu in August 2022. The sharp rise was due to supply chain issues and economic strain following the COVID-19 pandemic, which was further exacerbated by Russia’s invasion of Ukraine in early 2022. As a result of the war, many countries began looking for alternative sources, and Russian pipeline gas imports to the European Union declined as a result. Meanwhile, LNG was a great beneficiary, with LNG demand in Europe rising by more than ** percent between 2021 and 2023. How domestic natural gas production shapes prices As intimated, the United States’ position among the leaders of worldwide natural gas production is one of the main reasons for why prices for this commodity are so low across the country. In 2023, the U.S. produced more than ************ cubic meters of natural gas, which allays domestic demand and allows for far lower purchasing prices.

Graph and download economic data for Global price of Natural gas, EU (PNGASEUUSDM) from Jan 1990 to May 2025 about EU, gas, World, Europe, and price.

Winter natural gas prices in the United States are forecast to see a notable increase in 2022/23. U.S. consumers are expected to pay an average of 15.95 U.S. dollars per thousand cubic feet of natural gas. This would mean an increase of over two U.S. dollars and comes in the wake of many countries and regions currently embattled in an energy supply shortage.

Working gas held in storage facilities in the United States increased by 53 billion cubic feet in the week ending July 4 of 2025 . This dataset provides the latest reported value for - United States Natural Gas Stocks Change - plus previous releases, historical high and low, short-term forecast and long-term prediction, economic calendar, survey consensus and news.

In 2024, the industrial natural gas price in the United States was 3.93 U.S. dollars per thousand cubic feet. This was a decrease compared to the previous year. In 2008, the U.S. price of natural gas for industry peaked at 9.65 U.S. dollars per thousand cubic feet as a result of the Great Recession. Despite the increase in natural gas prices for the industry sector in recent years, natural gas prices for other sectors were much higher. Regional price variations across U.S. hubs Natural gas prices can vary significantly across different regions of the United States. In 2024, the Waha trading hub in the Permian basin recorded the lowest spot prices due to its proximity to productive oil and gas wells and limited pipeline capacity. Meanwhile, the Henry Hub, which serves as the U.S. natural gas benchmark, averaged 2.2 U.S. dollars per million British thermal units in 2024. Looking ahead, forecasts suggest that Henry Hub prices could more than double by 2026, driven by increased demand. Industry natural gas prices around the world Switzerland has some of the highest natural gas prices for the industrial sector. U.S. prices are especially low in comparison to European countries, which rely on imports. U.S. industrial natural gas consumers paid around one fourth of the price paid by Swiss consumers.

The Natural Gas Liquid Market is segmented based on product into Ethane, Propane, Isobutene, and Natural Gasoline. Ethane is the most dominant product due to its high demand as a petrochemical feedstock for producing ethylene. Propane is primarily used as a fuel for heating, cooking, and transportation. Isobutene is mainly used in the production of synthetic rubber. Natural gasoline is used as a blending component in motor fuels. Recent developments include: In April 2019,Hess Midstream Partners LP announced plans to increase natural gas processing capacity at the Toga gas facility by 150 million cubic feet per day, bringing total processing capacity north of the Missouri River to 400MMcf/d., In March 2023,Saudi Aramco announced record profits of $161 billion as gasoline prices skyrocketed following the Corona-virus pandemic. The figures outperformed ExxonMobil and Shell, which announced profits of $55.7 billion and $39.9 billion, respectively., In July 2019, Occidental Petroleum purchased Anadarko Petroleum, bringing with it a vast legacy of environmental violations, including the largest environmental contamination settlement in American history, involvement in the Deepwater Horizon BP disaster, and Clean Water Act fines.. Notable trends are: Growing government backing for NGL usage drives market growth..

The Oman Oil and Gas market size was valued at USD 4.36 million in 2025 and is expected to grow at a CAGR of 2.40% during the forecast period 2025-2033. Oman is the largest producer of oil and gas in the Middle East outside the Gulf Cooperation Council (GCC), with significant reserves of both commodities. The country's oil production has been steadily increasing in recent years, reaching a record high of 1.02 million barrels per day in 2022. Oman's natural gas production has also been growing, with the country currently producing around 10 billion cubic meters of gas per year. Key drivers of growth in the Oman Oil and Gas market include rising energy demand, increasing investment in exploration and production, and the development of new oil and gas fields. The government of Oman is also taking steps to diversify the country's economy away from oil and gas, which should create new opportunities for growth in the sector. Restraints on the growth of the Oman Oil and Gas market include the volatility of oil prices, the impact of climate change, and the emergence of renewable energy sources. Recent developments include: April 2023: Masirah Oil, a subsidiary of Singapore-headquartered independent Rex International, announced to explore its flagship asset offshore Oman, with its sights set on a production boost from the block 50 purchases. In addition, a block-wide review of exploration potential would be performed. Based on the results of an exploration review at Block 50, planning for acquiring additional targeted seismic would be implemented., March 2023: The Omani Ministry of Energy & Minerals offered domestic and international investors three oil and gas exploration areas as part of its latest licensing round. The tracts offered blocks 15, 36, and 54, where multiple companies have conducted seismic and drilling activities., January 2023: Shell Integrated Gas Oman BV, a subsidiary of Shell PLC, announced the beginning of gas production from the Mabrouk North Eastfield in Block 10 in Oman. Production from Block 10 is expected to touch 0.5 billion standard cubic feet of gas per day (bscf/d) by mid-2024, with the produced gas supplied to Oman's gas network that feeds local industries.. Key drivers for this market are: 4., Increasing Gas Production and Infrastructure4.; Increasing Exploration and Production Activities. Potential restraints include: 4., Increasing Gas Production and Infrastructure4.; Increasing Exploration and Production Activities. Notable trends are: Upstream Sector to Dominate the Market.

Household prices for natural gas in the United States reached 14.59 U.S. dollars per thousand cubic feet in 2024. This was a decrease compared to the previous year, which saw prices peak at more than 15 U.S. dollars. The 2023 price hikes were due to extreme winter weather events, which resulted in a decline in natural gas production and processing.

The size of the Ecuador Oil and Gas Midstream Market was valued at USD XX Million in 2023 and is projected to reach USD XXX Million by 2032, with an expected CAGR of > 1.03% during the forecast period. The oil and gas midstream market refers to the sector that encompasses the transportation, storage, and processing of crude oil, natural gas, and refined petroleum products. This segment acts as a crucial link between the upstream sector, which involves exploration and production, and the downstream sector, which focuses on refining and distribution. Midstream activities include the construction and operation of pipelines, storage facilities, and processing plants that facilitate the movement of hydrocarbons from production sites to refineries and end-users. Pipelines are the primary mode of transport in the midstream sector, as they provide a cost-effective and efficient means of moving large volumes of oil and gas over long distances. Storage facilities, on the other hand, play a vital role in managing supply and demand fluctuations, allowing companies to store excess production during low-demand periods and release it during peak demand times. Additionally, processing facilities are essential for removing impurities from raw hydrocarbons and converting them into market-ready products. Recent developments include: Oct 2022: Ecuador's state-run oil firm Petroecuador anticipates choosing a contractor to increase the Amistad offshore gas field's production capacity. To boost the field's natural gas production from its present level of 100 million cubic feet per day (mmcfd) to 24 mmcfd, the selected contractor would invest at least USD 500 million. The growing natural gas production will support the growth of natural gas supply and transportation across the country., Mar 2022: Frontera Energy Corporation announced that it had found 27.2 degrees API light crude oil on the Perico block at the Tui-1 exploration well in Ecuador.. Key drivers for this market are: 4., The Growing Demand for Solar Energy-Based Power Generation4.; Declining Photovoltaic System Prices. Potential restraints include: 4., The Country's Inefficient Electricity Grid Infrastructure. Notable trends are: Transportation Sector to Witness Growth.

The size of the Colombia Oil & Gas Midstream Industry market was valued at USD XX Million in 2023 and is projected to reach USD XXX Million by 2032, with an expected CAGR of 1.52">> 1.52% during the forecast period. The midstream sector of Colombia's oil and gas industry serves as a vital element within the nation's energy framework, concentrating on the transportation, storage, and distribution of hydrocarbons. This sector includes the necessary infrastructure and services to facilitate the movement of oil and gas from extraction sites to refineries, processing plants, and final consumers. Given Colombia's substantial hydrocarbon reserves, especially in the Llanos Basin and the Putumayo region, the midstream market holds significant importance. The industry operates through a comprehensive network of pipelines, storage facilities, and transportation systems, ensuring the effective and secure delivery of oil and gas products. Recent advancements feature investments aimed at expanding and upgrading pipelines to enhance both capacity and reliability. Furthermore, there is an increasing focus on modernizing infrastructure to improve operational efficiency and promote environmental sustainability. The market encounters challenges such as volatile global oil prices, regulatory ambiguities, and sporadic security concerns related to infrastructure. Nevertheless, Colombia's strategic role as a prominent energy exporter in the region, along with its ongoing initiatives to attract investment and elevate industry standards, fosters a favorable outlook for the midstream sector. As the nation progresses in developing its oil and gas resources, the midstream industry will be essential in bolstering economic growth and ensuring energy security. Recent developments include: October 2022: The construction of a 289-km OD natural gas pipeline from Canacol Energy Ltd's 300-MMscfd Jobo gas processing plant to Medellin, Colombia, was contracted out to Shanghai Engineering and Technology Corp. (SETCO). The pipeline's initial capacity is expected to be 100 MMscfd., May 2022: The Jobo-Medelln natural gas pipeline is to start construction, according to Colombian gas company Canacol. By December 2024, the 300-km (186-mile) pipeline is anticipated to be operational, carrying 100 million cubic feet per day (MMcf/d) of natural gas from natural gas resources along the Caribbean coast to Colombia's second-largest city.. Key drivers for this market are: , Government Policies for the Adoption of Energy-efficient Lighting Systems; Adoption of IoT with Lighting Systems. Potential restraints include: 4., The global shift toward renewable sources for electricity generation. Notable trends are: Pipeline Sector is Likely to Remain Stagnant.

The global glycol dehydration unit market is experiencing robust growth, driven by the increasing demand for natural gas and the expansion of oil and gas exploration and production activities worldwide. The market's value, while not explicitly stated, can be reasonably estimated based on typical industry growth rates and the mentioned CAGR (Compound Annual Growth Rate). Considering a substantial market presence and the numerous companies involved, a 2025 market size of approximately $2.5 billion seems plausible, given the various applications and capacities involved. This substantial size is further fueled by ongoing investments in upstream and downstream sectors of the energy industry, including refinery expansions and the development of new chemical plants. The market is segmented by application (natural gas, refineries, chemical plants, offshore production) and capacity (categorized by MSCFD—thousand standard cubic feet per day). The higher capacity segments are likely showing stronger growth due to the efficiency gains they offer large-scale operations. Technological advancements leading to more efficient and compact dehydration units, alongside rising concerns about environmental regulations, are also key drivers. However, market growth faces certain constraints. Fluctuations in energy prices, geopolitical instability impacting oil and gas production, and potential supply chain disruptions can affect market expansion. The competitive landscape is characterized by established players like Exterran, Schlumberger, and Enerflex, alongside several regional and specialized manufacturers. This competition is fostering innovation and driving down costs, benefiting end-users. Future growth will hinge on sustained investment in energy infrastructure, the continued demand for natural gas, and the successful navigation of regulatory and economic uncertainties. Further regional diversification of manufacturing and sales could also become a crucial factor in driving future market penetration. The forecast period (2025-2033) suggests continued expansion, but accurate projection depends heavily on macro-economic and geopolitical factors.

The Ecuadorian oil and gas midstream market, encompassing transportation, storage, and LNG terminals, is experiencing steady growth, projected to maintain a CAGR above 1.03% from 2025 to 2033. While precise market size data for 2025 is unavailable, industry analysis suggests a figure in the tens of millions of dollars, given Ecuador's oil production levels and existing infrastructure. Key drivers include increasing domestic demand for energy, growing investments in infrastructure modernization, and government initiatives to improve energy security. The transportation segment is likely the largest, driven by the need to efficiently move crude oil and refined products across the country. Storage solutions are also crucial for maintaining supply chain stability and managing fluctuations in production. The LNG terminal segment, though potentially smaller, presents significant growth opportunities due to rising global demand for LNG and potential export opportunities. However, market growth faces constraints such as the volatility of global oil prices, potential regulatory hurdles, and infrastructure limitations. Companies like Eni SpA, OCP Ecuador, Techint, Sycar LLC, and Occidental Petroleum Corporation are actively shaping this market through investments and operational activities. Significant opportunities exist for expansion and modernization within the Ecuadorian oil and gas midstream sector. Foreign direct investment (FDI) will likely play a crucial role in funding large-scale infrastructure projects. Technological advancements, particularly in pipeline management and storage optimization, are expected to enhance efficiency and reduce operational costs. Furthermore, a focus on sustainable practices and environmental regulations will be increasingly important in shaping the industry's trajectory. The market's future success hinges on a balance between robust infrastructure development, effective regulatory frameworks, and environmentally conscious operations. Recent developments include: Oct 2022: Ecuador's state-run oil firm Petroecuador anticipates choosing a contractor to increase the Amistad offshore gas field's production capacity. To boost the field's natural gas production from its present level of 100 million cubic feet per day (mmcfd) to 24 mmcfd, the selected contractor would invest at least USD 500 million. The growing natural gas production will support the growth of natural gas supply and transportation across the country., Mar 2022: Frontera Energy Corporation announced that it had found 27.2 degrees API light crude oil on the Perico block at the Tui-1 exploration well in Ecuador.. Notable trends are: Transportation Sector to Witness Growth.

The cryogenic equipment market is experiencing robust growth, driven by increasing demand across diverse sectors. The market, valued at approximately $XX million in 2025 (assuming a logical extrapolation from the provided CAGR and study period), is projected to exhibit a Compound Annual Growth Rate (CAGR) exceeding 4% from 2025 to 2033. This expansion is fueled by several key factors. The burgeoning LNG (liquefied natural gas) industry, coupled with the expanding need for cryogenic storage and transportation solutions in healthcare (e.g., cryopreservation of biological samples and medical gases) and industrial applications (e.g., food processing and metallurgy), are significant contributors to market growth. Technological advancements in cryogenic equipment design, leading to enhanced efficiency, safety, and reduced operational costs, further propel market expansion. Furthermore, stringent environmental regulations promoting cleaner energy sources and reduced emissions indirectly boost the demand for cryogenic equipment used in carbon capture and storage technologies. However, market growth faces some challenges. High initial investment costs associated with cryogenic equipment can be a barrier to entry for some businesses. Moreover, the complexity of cryogenic technologies requires specialized expertise for installation, maintenance, and operation, potentially limiting wider adoption. Despite these restraints, the long-term prospects for the cryogenic equipment market remain positive, largely due to continued growth in sectors such as energy, healthcare, and industrial manufacturing. Key players like Linde PLC, Chart Industries Inc., and Honeywell International Inc. are strategically positioned to capitalize on these opportunities through innovation, strategic partnerships, and geographic expansion. The market is further segmented geographically, with North America and Europe currently holding substantial shares, though emerging economies in Asia are exhibiting rapid growth potential. Recent developments include: In January 2022, Saulsbury was awarded the EPC contract for the design and installation of two cryogenic processing facilities in the Midland Basin. The facilities, designed with a base-rated capacity of 200 million standard cubic feet per day (MMSCFD) each, mark Saulsbury's 61st and 62nd cryogenic processing facility projects since 2006, representing nearly 11 billion cubic feet per day (BCFD) of processing capacity, and its 23rd and 24th cryogenic processing facility in the West Texas region., In October 2021, Chemie-Tech was awarded an Engineering, Procurement, Construction & Commissioning contract from HPCL Rajasthan Refinery Ltd (HRRL) for Cryogenic Double Wall Storage Tanks (DWST) and associated facilities - Package 7 (Part-A) at HPCL Rajasthan Refinery Ltd in Rajasthan, India. The scope of the contract involves project management, residual process design, detailed design and engineering, procurement, construction, pre-commissioning and commissioning with single-point responsibility of above ground, flat bottom, vertical, full containment type double-wall storage tank (outer tank with RCC post-tension wall and inner tank 9% Ni Steel) with Packages such as BOG Compressor, Ethylene Vaporisor, Propylene Heating, Glycol Makeup, Cold-Blowdown system, In-tank pumps, etc.. Notable trends are: Tanks Segment Expected to Experience Significant Market Growth.

Union-Kern-A.O.G. Moonie No. 1 was the third wildcat drilled by Union Oil Development Corporation in its current exploratory effort in the Surat Basin in Queensland. The drilling of the initial test …Show full descriptionUnion-Kern-A.O.G. Moonie No. 1 was the third wildcat drilled by Union Oil Development Corporation in its current exploratory effort in the Surat Basin in Queensland. The drilling of the initial test in the Basin, Union-Kern-A.O.G. Cabawin No. 1, resulted in a sub-commercial discovery of oil in an eight-foot sand body (9928-9936 feet) in the Permian Kianga Formation. The second test, Union-Kern-A.O.G. CabawinEast No. 1, was programmed on a distinct closure separated from the domal closure of Cabawin No. 1 by a major transverse fault. The test was designed to evaluate the thesis that the oil bearing sandstone encountered in the first well might thicken appreciably eastward. Cabawin East was dry; the Permian oil bearing sandstone was not developed at the second location. After additional geophysical work, Union-Kern-A.O.G. Moonie No. 1 was programmed approximately 20 miles south of Cabawin East as a structural test of the petroleum potential of the Triassic lower Bundamba sandstones. At the location of the test, sands of the lower member of the Bundamba Formation in domal closure overlie a truncated and faulted Permian section. The desirability of the test was suggested from information gained in the Cabawin area where permeable lower Bundamba sands were indicated to be the most favourable reservoir rocks, and where the Permian section was indicated to be the probable source of the oil encountered. At the location of the test a maximum of 150 feet of vertical closure over ten square miles was indicated in the Bundamba section. No closure could be postulated for the steeply dipping Permo-Carboniferous sequence unconformably present beneath the Bundamba. The test was based on the thesis that oil generated in the Permian section would migrate up dip, and be trapped in the porous sands of the Bundamba closure. To enhance the prospect further, seismic work indicated that a portion of the lower Bundamba which consisted of a less permeable section in the Cabawin wells, had been overlapped at the proposed location and that porous and permeable sands of the unit might rest directly on the unconformity. The well was spudded in on 12th November, 1961; 13 3/8" casing was cemented at 1636 feet, and drilling and coring was continued to a depth of 5925 feet. At that depth a 74-minute open-hole formation test of the interval 5816-5925 feet yielded black 48 API gravity oil flowing at an estimated rate of 250 barrels per day and water (29 grains/gallon), at an estimated rate of 250 barrels per day. Gas accompanying the flow was estimated at 200 Mcf/D. The well was drilled and cored ahead to a total depth of 6106 feet. Casing (5 1/2") was cemented at 5950 feet, and the well was completed through perforations of the interval 5798-5840 feet. A sustained testing programme was conducted from 23rd December, 1961 to 18th February, 1962. At the end of this period the well was producing 666 barrels per day of 45 API gravity oil with 124 Mcf/D of gas through 18/64" choke, with casing and tubing wellhead pressures at 600 p.s.i. and 560 p.s.i. respectively. A total of 7445 barrels of crude oil and 1320 Mcf of gas were produced during the testing period. The well was shut in on 18th February, 1962 for final pressure and temperature surveys and was suspended on 21st February, 1962, retained in a condition for production at any future time.

In 2020, the average current natural gas production rate stood at 6.6 billion cubic feet per day. As of the same date, Egypt had a natural gas production capacity of 7.2 billion cubic feet per day.