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Global Oil & Gas Limited (ASX: GLV) (Company) is pleased to announce that is has been offered a Technical Evaluation Agreement (TEA) for a 4,858km2 oil and gas exploration block offshore Peru. The Company will hold 80% of the TEA with project partner, US based oil and gas exploration company Jaguar Exploration, Inc. (Jaguar), holding the remaining 20%.
Highlights
- Global has been offered the rights to a 4,858km2 oil and gas block in proven hydrocarbon bearing basins offshore Peru, boarding the prolific (+1.6 Billion Barrels produced) Talara basin (TEA LXXXVI previously Z-70)
- The Company and Jaguar Exploration, Inc (US based partner) will now move to finalise formal agreements with Perupetro (the Peruvian national oil regulator) for its 100% interest in the block (80% Global and 20% Jaguar)
- Previous production of 4,000 bopd at the excised Corvina field incorporated within the block
- Located immediately south of the block is the Alto- Pena Negra oil field, one of Peru’s most productive fields, currently producing around 3,000 bopd with total historical production of more than 143 million barrels of oil
- Historical corporate transactions in the region of up to US$900 million Dollars
- Data from 7 historical 2D seismic campaigns and more than 3,800km2 of historical 3D seismic has been secured
- No significant expenditure commitments for the TEA
- Global aim to generate Prospective Resources to facilitate potential third-party investment and/or farmin
Fig 1. TEA LXXXVI location
Managing Director Patric Glovac commented:
“Being offered this globally significant 4,858km2 (over 1.1 million acres) offshore oil and gas opportunity in Peru has the potential to be transformational for the Company.
The nearby oil discoveries and petroleum refinery close to the offshore block make this an enviable address for global oil and gas players. Seven 2D seismic surveys and more than 3,800km2 of 3D seismic has been received and is now being processed to identify leads, prospects and Certified Prospective Resources.
The Company is in the process of creating a comprehensive data room to facilitate the process of marketing this opportunity to prospective project investors and/or joint venture partners.
This world-class asset is an incredible opportunity for the Company to comprehensively collate all existing information, generate certified Prospective Resources and generate compelling drill targets
We look forward to finalising the formal agreements over the coming weeks with both Jaguar & Perupetro”.
The Company and Jaguar have been considered as a “Qualified Subjects” by Perupetro (the Peruvian national oil regulator) and can now assume obligations for one hundred percent (100%) participation in a Technical Evaluation Agreement (CET) on area LXXXVI, subject to formal contracts being entered into between the parties and Perupetro which is expected to occur over the coming weeks.
The oil and gas block is located in the gulf of Guayaquil in water depths that range from 100m to 1,500m, straddling the Tumbes-Progreso and Talara basins. Both basins host historical producing oil and gas fields, with the latter incorporating one of Peru’s most productive hydrocarbon plays.
Fig 2. Tumbes-Progreso and Talara Basins
The block is surrounded by, and incorporates, multiple historic and currently producing oil and gas fields. The southeast of the block borders the Alto-Pena Negra oil field which is one of Peru’s most productive fields, currently producing around 3,000 barrels of oil per day (bopd) and with total historical production of more than 143 million barrels of oil.
In the northeast, the block incorporates the excised Corvina oil field which generated past production rates of up to 4,000 barrels of light oil per day (28.45⁰ API).
The southern border of the TEA is also only 70km from the Talara crude oil refinery which received production from the Corvina field.
Exploration Opportunity
Historical exploration over the TEA has been intermittent with a clear misalignment between seismic and the drilling of the exploration wells. Three early 1970s wildcat wells, drilled before the running of any seismic, encountered oil and gas followed by only one more exploratory well three decades later after the running of seven 2D and four 3D (3,800km2) seismic campaigns.
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This article includes content from Global Oil and Gas Limited, licensed for the purpose of publishing on Investing News Australia. This article does not constitute financial product advice. It is your responsibility to perform proper due diligence before acting upon any information provided here. Please refer to our full disclaimer here.
GLV:AU
Oil and Gas Price Update: Q1 2025 in Review
“The macroeconomic conditions that underpin our oil demand projections deteriorated over the past month as trade tensions escalated between the United States and several other countries,” a March oil market report from the International Energy Agency (IEA) notes, highlighting the downside risks of US tariffs and retaliatory measures.
The instability and weaker-than-expected consumption from advanced and developing economies prompted the IEA to downgrade its growth estimates for Q4 2024 and Q1 2025 to about 1.2 million barrels per day.
Despite the uncertain outlook, an announcement that OPEC+ would extend a 2.2 million barrel per day production cut into Q2 added some support to the market amid global growth concerns and rising output in the US.
Prices spiked at the end of March, pushing both benchmarks to within a dollar of their 2025 start values. However, the rally was short-lived and prices had plummeted by April 9.
Oil prices fall as OPEC hikes output and supply risks mount
WTI price performance, December 31, 2024, to April 23, 2025.
Chart via the Investing News Network.
Sinking to four year lows, Brent and WTI fell below the critical US$60 per barrel threshold, to US$58.62 (Brent) and US$55.38 (WTI), lows not seen since April 2021. The decline saw prices shed more than 21 percent between January and April shaking the market and investor confidence.
“We're into the supply destruction territories for some of the high cost producers,” Ole Hansen, head of commodity strategy at Saxo Bank, told the Investing News Network. “It will not play out today or tomorrow, because a lot of these producers are forward hedging as part of their production.”
Watch Hansen discuss where oil and other commodities are heading.
According to Hansen, if prices remain in the high US$50 range US production will likely decrease, aiding in a broader market realignment. "Eventually we will see production start to slow in the US, probably other places as well, and that will help balance the market,” the expert explained in the interview. “Helping to offset some of the risk related to recession, but also some of the production increases that we're seeing from OPEC.”
In early April, OPEC+ did an about face when it announced plans for a significant increase in oil production, marking its first output hike since 2022. The group plans to add 411,000 barrels per day (bpd) to the market starting in May, effectively accelerating its previously gradual supply increase strategy.
Although the group cited “supporting market stability” as the reasoning behind the increase, some analysts believe the decision is a punitive one targeted at countries like Iraq and Kazakhstan who consistently exceed production quotas.
“(The increase) is basically in order to punish some of the over producers,” said Hansen. He went on to explain that Kazakhstan produced 400,000 barrels beyond its quota.
If these countries return to their agreed limits, it could offset OPEC’s planned production hikes.
At the same time, US sanctions on Iran and Venezuela may tighten global supply further, while a growing military presence in the Middle East also signals rising geopolitical risks, particularly involving Iran.
Oil price forecast for 2025
As such Hansen expects prices to fluctuate between US$60 to US$80 for the rest of the year.
“(I am) struggling to see, prices collapse much further than that, simply because it will have a counterproductive impact on supply and that will eventually help stabilize prices,” said Hansen.
Hansen’s projections also fall inline with data from the US Energy Information Administration (EIA). The organization downgraded the US$74 Brent price forecast it set in March to US$68 in April.
The EIA foresees US and global oil production to continue rising in 2025, as OPEC+ speeds up its planned output increases and US energy remains exempt from new tariffs.
Starting mid-year, global oil inventories are projected to build. However, the EIA warns that economic uncertainty could dampen demand growth for petroleum products, potentially falling short of earlier forecasts.
“The combination of growing supply and lower demand leads EIA to expect the Brent crude oil price to average less than US$70 per barrel in 2025 and fall to an average of just over US$60 per barrel in 2026,” the April report read.
Supply concerns add tailwinds for natural gas
On the natural gas side, Q1 was marked by tight conditions amid rising demand. A colder-than-normal winter led to increased consumption, with US natural gas withdrawals in Q1 exceeding the five-year average.
Starting the year at US$3.59 per metric million British thermal units, prices rose to a year-to-date high of US$4.51 on March 10. Values pulled back by the end of the 90 day period to the US$4.09 level, registering a 13.9 percent increase for Q1.
"Cold weather during January and February led to increased natural gas consumption and large natural gas withdrawals from inventories,” a March report from the EIA explains.
Natural gas price performance, December 31, 2024, to April 23, 2025.
Chart via the Investing News Network.
“(The) EIA now expects natural gas inventories to fall below 1.7 trillion cubic feet at the end of March, which is 10 percent below the previous five-year average and 6 percent less natural gas in storage for that time of year than EIA had expected last month," the document continues.
Natural gas price forecast for 2025
Following record setting demand growth in 2024 the gas market is expected to remain tight through 2025, amid market expansion from Asian countries.
The IEA also pointed to price volatility brought on geopolitical tensions as a factor that could move markets.
“Though the halt of Russian piped gas transit via Ukraine on 1 January 2025 does not pose an imminent supply security risk for the European Union, it could increase LNG import requirements and tighten market fundamentals in 2025,” the organization notes in a gas market report for Q1.
Although the market is forecasted to remain tight the IEA expects growth in global gas demand to slow to below 2 percent in 2025. Similarly to 2024’s trajectory, growth is set to be largely driven by Asia, which is expected to account for almost 45 percent of incremental gas demand, the report read.
THe US-based EIA has a more optimistic outlook for the domestic gas sector, projecting the annual demand growth rate to be 4 percent for 2025.
“This increase is led by an 18 percent increase in exports and a 9 percent increase in residential and commercial consumption for space heating,” an April EIA market overview states.
The report attributes the expected export growth to increased liquefied natural gas (LNG) shipments out of two new LNG export facilities, Plaquemines Phase 1 and Golden Pass LNG.
Venture Global's (NYSE:VG) Plaquemines LNG facility in Louisiana commenced production in December 2024 and is currently in the commissioning phase.
Once fully operational, it is expected to have a capacity of 20 million metric tons per annum. The facility has entered into binding long-term sales agreements for its full capacity
Golden Pass LNG, a joint venture between ExxonMobil (NYSE:XOM) and state-owned QatarEnergy, is under construction in Sabine Pass, Texas. The project has faced delays due to the bankruptcy of a key contractor, with Train 1 now expected to be operational by late 2025 . Upon completion, Golden Pass LNG will have an export capacity of up to 18.1 million metric tons per annum.
The EIA forecasts natural gas prices to average US$4.30 in 2025, a US$2.10 increase from 2025. Farther ahead the EIA has a more modest forecast of US$4.60 for 2026.
Don’t forget to follow us @INN_Resource for real-time updates!
Securities Disclosure: I, Georgia Williams, hold no direct investment interest in any company mentioned in this article.
Editorial Disclosure: The Investing News Network does not guarantee the accuracy or thoroughness of the information reported in the interviews it conducts. The opinions expressed in these interviews do not reflect the opinions of the Investing News Network and do not constitute investment advice. All readers are encouraged to perform their own due diligence.
Jupiter Energy
Investor Insight
Jupiter Energy’s strong cash flow, substantial proven recoverable reserves, and strategic foothold in resource-rich Kazakhstan present a compelling investment opportunity. Its commitment to sustainability—reinforced by a recent strategic investment in 100 percent gas utilization infrastructure—further enhances its long-term investor appeal.
Overview
Jupiter Energy Limited (ASX:JPR) is an established oil exploration and production company that operates three oilfields in Kazakhstan. The company is currently producing approximately 600 to 700 barrels of oil per day from its licensed fields, having successfully navigated Kazakhstan’s regulatory and operational landscape since 2008. Its operations are fully compliant, with its three full commercial production licenses secured until 2045/46/46.
Jupiter Energy is recognized as a reliable operator in Kazakhstan, holding 100 percent ownership of its licenses, which span approximately 123 sq km in the oil-rich Mangistau region. Strategically located near the port city of Aktau, its license area benefits from proximity to established oil processing facilities and extensive oil and gas infrastructure, including key pipeline connections to the country’s major refineries (see Figure 1).
The company has successfully navigated regulatory requirements to achieve full commercial production across its three oilfields—Akkar East, Akkar North (East Block), and West Zhetybai—all operating under 25-year commercial licenses. Jupiter’s strong compliance and operational framework reinforce its commitment to long-term, sustainable production in Kazakhstan.
Jupiter Energy’s reserve base has been independently confirmed by a Sproule International competent person’s report (CPR), effective 31 December 2023, detailing significant recoverable reserves.
According to the Sproule International CPR, released in January 2024, Jupiter Energy’s recoverable reserves under the SPE/PRMS classification are as follows:
- 1P Reserves: 14.691 million barrels (mmbbls)
- 2P Reserves: 36.487 mmbbls
- 3P Reserves: 46.796 mmbbls
These figures confirm Jupiter’s substantial reserve base, and correlate with its Kazakh State Approved Reserves which are recorded at approximately 52 mmbbls recoverable (using the GOST C1 + C2 classification methodology) (see Figure 2).
Figure 1: Total reserves for the Mangistau basin are estimated to be in excess of 5 billion barrels including two large oil fields, Uzen and Zhetybai.
On November 15, 2024, Jupiter Energy announced the completion of its gas pipeline integration project, connecting the Akkar East and Akkar North (East Block) oilfields to neighboring gas utilization facilities operated by its larger neighbour, MangistauMunaiGas (MMG). This integration ensures 100 percent utilization of all its associated gas, aligning with Kazakhstan’s environmental goals and enabling the Company to drill further wells whilst continuing to comply with Kazakhstan’s strict 100% gas utilisation policy.
The company plans to connect the West Zhetybai oilfield to this infrastructure as this oilfield is further developed. This project strengthens Jupiter’s relationships with MMG and the Kazakh Ministry of Energy, facilitating long-term production under its commercial licenses and enabling it to sell its oil into both the Kazakh domestic market as well as international oil markets.
Company Highlights
- Operating in Kazakhstan since 2008, with three oilfields under licence. The area is known as Block 36 (formerly Block 31).
- Holds commercial production licenses for all three of its oilfields, valid until 2045/2046/2046.
- Current production is approximately 640 barrels per day from four production wells, with plans to increase to approximately 1,000 barrels per day during 2025, with the drilling of a new production well (assuming success).
- Recent independent after-tax NPV of the oilfields (using a 20 percent discount) of US$180 million. This compares favourably to the Company’s current EV of approximately AU$63.5 million (~US$38 million) – based on a share price of AU$0.03 and balance sheet debt of ~$US15.1m.
- Operates in West Kazakhstan in the Mangistau region, a proven area for Kazakhstan’s oil reserves (see Figure 1).
- The company is cash flow positive at an operational level.
- Key shareholders include long term holders, Waterford (60 percent) and Blackbird Trust (21 percent).
- Jupiter’s recent strategic investment in its onfield gas utilisation infrastructure, signifies its commitment to sustainable operations, contribution to the welfare of the local community and support for Kazakhstan’s longer term commitment to a carbon free operating environment in the oil local industry.
Key Project: Block 36
Figure 2: Outline of Jupiter Energy’s oilfields located on Block 36
Block 36 is Jupiter Energy’s flagship project located in the Mangistau Basin of West Kazakhstan. Covering an area of approximately 123 sq km, it lies in a highly prospective region with proven oil reserves. The company acquired extensive 3D seismic data over the entire block and surrounding areas, totaling 235 sq km, which then enabled the identification of multiple drilling targets. The current reserve base covers 35 sq km, with further exploration targets available for drilling on the licence area, when funding for further exploration wells is available.
Jupiter has drilled nine wells on Block 36, targeting the Akkar North (East Block), Akkar East, and West Zhetybai oilfields (see Figure 3). The current production from Block 36 is approximately 640 barrels of oil per day, with plans to increase output to around 1,000 barrels per day during 2025, assuming success with the drilling of a new production well in 2H 2025. Further increases in production may also come via the workovers of existing wells and the drilling of further new wells, planned from 2025 to 2030.
Figure 3: Well locations on Block 36
At the helm of Jupiter Energy is a highly experienced corporate and technical leadership team, driving the company towards achieving its goals and increasing shareholder value.
Management Team
Geoff Gander - Chairman and CEO
Geoff Gander graduated from the University of Western Australia in 1984, where he completed a Bachelor of Commerce degree. He has been involved in the listing and running of public companies since 1994. He was appointed as a director of Jupiter Energy in January 2005 and he is currently responsible for the overall operational leadership of the company, as well as investor relations and group corporate development.
Baltabek Kuandykov - Non-executive Director
Baltabek Kuandykov is currently the president of Meridian Petroleum, a privately held Kazakh oil & gas company. He was formerly the president of Nelson Resources, an oil development and production company operating in Kazakhstan which was listed on the Toronto Stock Exchange until its acquisition by Lukoil in 2005. Kuandykov has considerable experience in the oil and gas industry in the region, having served as president of Kazakhoil (predecessor of the Kazakh State oil company KazMunaiGas), and is a well-respected consultant to Chevron Overseas Petroleum on CIS projects. He also worked in a senior capacity for Kazneftegazrazvedka and was president of Kazakhstancaspishelf. Kuandykov has extensive government experience in Kazakhstan, having served as deputy minister of geology, head of the oil and gas directorate at the Ministry of Geology, and was deputy minister of energy and fuel resources.
Alexey Kruzhkov - Non-executive Director
Alexey Kruzhkov holds an engineering degree and an MBA with over 10 years’ experience working in the investment industry, focusing primarily on the oil & gas, mining and real estate sectors. He has served as a director on the boards of companies listed in Canada and Norway. He is a member of the executive team of Waterford Finance and Investment Limited. He holds British and Russian citizenship.
Alexander Kuzev - Non-executive Director
Alexander Kuzev is an oil industry professional with over 26 years of experience. Most of his career has been spent working in the Former Soviet Union with much of that time responsible for the overall management of field operations with a focus on production sustainability, technology and field maintenance. He brings an important technical advisory skill set to the Jupiter Energy board, as well as in-country experience, having been involved with various Kazakhstan-based oil and gas operations since the late 1990s.
Keith Martens - Non-executive Director
Keith Martens has over 40 years’ experience as an oil finder and manager around the world. He has served as a technical advisor and consultant to a number of Australian oil & gas companies, and was instrumental in the discovery of Jupiter’s Akkar East and West Zhetybai oil fields when he was consulting to Jupiter Energy between 2007 and 2014. More recently, Martens has been working on the Eastern Margin of the Permian Basin in Texas with Winchester Energy and in the Paradox Basin in Utah and Colorado, as both lead explorationist and non-executive chairman of ASX listed Grand Gulf Energy (ASX:GGE).