ReconAfrica to Commence High-Stakes Drilling at Naingopo Well, Targeting Major Oil and Gas Reserves in Namibia

Overview and Key Points.
ReconAfrica is set to begin exploration drilling at the Naingopo Well in Namibia, as part of their operations under Petroleum Exploration Licence 73 (PEL 73). The company is relocating its camp and drilling rig from a previous site to Naingopo, with drilling scheduled to start by the end of the month. The target is significant, with estimates of 163 million barrels of unrisked prospective oil resources and 843 billion cubic feet of unrisked prospective natural gas resources.
 Current Status
– Relocation and Setup: The drilling rig, Jarvie-1, is being moved to the new site and is expected to be operational soon. Maintenance and certifications have been completed without issues.
– Drilling Timeline: The drilling is planned to start by the end of the month and will take approximately 90 days.
– Target: Multiple reservoir intervals in the Damara Fold Belt, with both oil and gas potential.
– Preparations: The conductor hole is already drilled, and the operations team is fully prepared with necessary equipment on-site or en route.
 Leadership Comments.
– Brian Reinsborough (President and CEO): Expressed optimism about the progress and smooth relocation process.
– Chris Sembritzky (SVP Exploration): Emphasized the importance of this first well in the Damara Fold Belt and the extensive preparatory work that has been done.
– Nick Steinsberger (SVP Drilling and Completions): Highlighted the readiness of the operations team and the mix of experienced personnel.
– Strategic Importance: This drilling is a pivotal step in testing the potential of the Damara Fold Belt, a region with multiple mapped prospects and leads.
– Economic Impact: If successful, the exploration could significantly boost ReconAfrica’s resource portfolio and contribute to Namibia’s oil and gas industry.
– Joint Venture: The joint venture process is advancing, aiming to finalize before drilling begins, which could provide additional resources and expertise.
Broader Context and Analysis
– Global Energy Landscape: The potential discovery of substantial oil and gas resources in Namibia could position the country as a new player in the global energy market. This is particularly relevant as the world transitions to a mix of energy sources.
Exploration Challenges: Exploration drilling is inherently risky, and while the prospects are promising, there are uncertainties. Historical data and geological surveys provide confidence, but actual drilling results will be crucial.
– Technological and Operational Readiness: The use of the Jarvie-1 rig, along with a seasoned team, underscores ReconAfrica’s preparedness and commitment to minimizing operational risks.
The upcoming exploration drilling at ReconAfrica’s Naingopo Well is a significant development with the potential to unlock substantial oil and gas resources in Namibia. The company’s thorough preparations and strategic approach highlight the importance of this project. However, as with all exploration activities, the outcomes remain uncertain until drilling is completed and results are analyzed. This project could have far-reaching implications for both ReconAfrica and the broader energy market, contingent on the success of the drilling operations.

You Don’t Need to Be a Risk-Taker to Succeed in Business Ventures (Seriously)

To the degree you understand this, you’ll experience the relief of pressure from what everyone else is telling you you “should” do: take risks.

You simply do NOT need to take risks to make your new business ventures successful.

I’m not saying they don’t help.

I’m not saying it’s a bad thing to be a risk-taker.

I’m not saying risks don’t matter. And I’m not saying you shouldn’t be courageous and brave.

You can too. Solid. Still friends? Cool. But it’s not a requirement for successful ventures.

Entrepreneurship is often associated with the idea that high risk leads to high reward.

The media perpetuates stories of daring moves paying off, glorifying risk-taking as essential for success.

However, the reality is different:

– High Failure Rates: Many new ventures fail due to excessive risk-taking.

– Financial and Emotional Toll: Failed ventures impact finances and mental health.

– Sustainability Issues: Businesses built on high-risk models struggle to maintain long-term success.

– Misrepresentation of Success: Media bias toward risk-taking creates a skewed view of entrepreneurial success.

 A Smarter Approach: Sustainable Opportunity Capitalization.

– Calculated Risks: Make informed decisions based on data and market research.

– Market Feasibility: Understand the feasibility of your idea to minimize risk.

– Steady Growth: Prioritize sustainable growth over rapid expansion.

– Flexibility and Adaptability: Be open to pivoting based on market feedback.

Addressing Common Misconceptions

 High Risk Equals High Reward?

– Rebuttal: While some high-risk ventures succeed, many more fail. Building steadily increases success chances.

– Evidence: Research shows businesses focused on steady growth are more likely to succeed long-term.

Playing It Safe?

– Rebuttal: Taking calculated risks isn’t playing it safe—it’s making strategic decisions based on data.

Successful entrepreneurs are often calculated risk-takers, weighing options carefully.

Implementation of Sustainable Approach

– Market Research: Understand the feasibility of your idea to minimize risk.

– Business Planning: Create achievable goals and timelines.

– Funding Strategies: Explore funding options without unnecessary risks.

– Risk Management: Identify and mitigate potential risks.

Entrepreneurship doesn’t have to be a high-stakes gamble. By focusing on sustainability, calculated risks, and steady growth, entrepreneurs can build successful businesses without risking everything. Let’s embrace a smarter, more strategic approach to entrepreneurship and pave the way for sustainable success.

Zanzibar Extends 1st Licensing Round Deadline-An analysis

Key Points of the Article

  1. Extension of Proposal Deadline:

– The Zanzibar government has extended the deadline for submitting proposals for eight offshore oil and gas blocks until December 16, 2024. This extension provides an additional three months for interested parties to prepare their bids.


  1. Reason for Extension:

– The extension was announced by Minister Shaaban Ali Othman from the Ministry of Blue Economy and Fisheries. The decision came after global promotion campaigns revealed that the original deadline was not favorable for many international oil companies (IOCs).

  1. Licensing Round Schedule:

– The article mentions that there is a new schedule for the licensing round, accessible via a provided link.


  1. Implications for International Oil Companies (IOCs):

– The extension shows that the Zanzibar government is responsive to the needs of potential investors, aiming to create a more favorable and competitive environment. This could increase the likelihood of higher quality and more numerous proposals, enhancing the chances of successful exploration and development.

  1. Strategic Importance:

– Offshore oil and gas exploration is a significant economic opportunity for Zanzibar. By adjusting the timeline, Zanzibar is likely trying to maximize participation from IOCs, which could bring in advanced technology, expertise, and substantial investments.

  1. Market Dynamics:

– The global oil and gas market is currently volatile, with fluctuations in prices and demand. Extending the deadline allows companies to better evaluate market conditions and their own strategic positions before committing to significant investments.

  1. Promotion Campaigns:

– Zanzibar’s proactive promotion campaigns indicate a strategic effort to attract foreign investment. This approach can position Zanzibar as an attractive destination for oil and gas exploration in the competitive East African market.

Broader Context

  1. Regional Competition:

– East Africa is emerging as a new frontier for oil and gas exploration, with countries like Mozambique and Tanzania already discovering significant reserves. Zanzibar’s efforts to attract IOCs can be seen as a move to compete with its neighbors and establish itself as a key player in the region.

  1. Economic Impact:

– Successful licensing and subsequent oil and gas development could have a transformative impact on Zanzibar’s economy, potentially providing revenue streams, creating jobs, and fostering ancillary industries.

  1. Environmental and Social Considerations:

– Oil and gas exploration carries environmental risks and potential social impacts. Zanzibar will need to ensure that exploration and extraction are conducted sustainably and responsibly, balancing economic benefits with environmental protection and social well-being.

Key Updates.

  1. Market Trends:

– Keeping an eye on the latest trends in the global oil and gas market will be crucial for potential bidders. Changes in oil prices, technological advancements, and geopolitical developments can influence the attractiveness of the Zanzibar blocks.

  1. Regulatory Developments:

– Any updates to Zanzibar’s regulatory framework or changes in regional policies affecting oil and gas exploration could impact the licensing process and investor decisions.

  1. Technological Innovations:

– Advances in exploration and extraction technologies can make previously unviable reserves economically feasible. Monitoring these innovations will be important for both the government and potential investors.


Zanzibar’s extension of the proposal deadline for offshore oil and gas blocks demonstrates its commitment to attracting significant international investment and competing in the East African oil and gas sector. This strategic move could enhance the quality and quantity of proposals received, ultimately benefiting Zanzibar’s economy. However, it’s crucial for all stakeholders to consider market conditions, regulatory environments, and technological advancements to make informed decisions.

The announcement included a link to the new licensing round schedule found here.


Analysis of Sintana Energy’s Acquisition in Namibia’s Orange Basin

Sintana Energy, a Canadian oil and natural gas exploration company, has acquired a significant stake in Giraffe Energy Investments. This acquisition gives Sintana a foothold in the Orange Basin off the coast of Namibia, specifically within petroleum exploration license (PEL) 79. This license covers blocks 2815 and 2915, which are near areas operated by major players like BW Energy, Rhino Resources, and Shell.

Sintana’s deal involves purchasing an initial 49% stake in Giraffe Energy for $2 million. Giraffe Energy holds a 33% stake in PEL 79, with NAMCOR, Namibia’s national petroleum corporation, holding the remaining 67%. Sintana has an option to increase its ownership up to 67% within five years for an additional $1 million.

This acquisition is strategically significant given recent discoveries in the region, such as Galp’s Mopane, which suggest promising opportunities for new exploration and potential oil finds. The move by Sintana is part of a broader trend where numerous companies are entering Namibia’s Orange Basin, indicating the region’s growing importance in the global energy market.

#### Expanding Beyond the Article

This acquisition is part of a larger trend of increased activity and investment in Namibia’s Orange Basin. Notably, Azule Energy recently acquired a 42.5% interest in Block 2914A in PEL 85. This interest highlights the competitive landscape and potential of the Orange Basin, as more companies recognize its untapped resources.

Furthermore, recent technological advancements and successful discoveries in adjacent blocks enhance the prospects for new entrants like Sintana. These developments may lead to more efficient exploration techniques and higher chances of successful drilling, which could transform Namibia into a significant player in the global oil market.

To summarize, Sintana Energy’s strategic acquisition in Namibia’s Orange Basin is a calculated move to capitalize on the region’s growing potential for oil exploration. The investment reflects a broader industry trend, with many companies positioning themselves in this promising area. Key takeaways include:

– Sintana’s acquisition of a 49% stake in Giraffe Energy, potentially increasing to 67%.
– The significance of PEL 79 in the Orange Basin, with NAMCOR holding a majority stake.
– The broader trend of increased interest and investment in Namibia’s Orange Basin by multiple energy companies.

Here are some critical data points to consider:

Investment Details: Sintana’s $2 million investment for 49% in Giraffe, with an option to increase to 67% for an additional $1 million.
– PEL 79 Coverage: This license encompasses blocks 2815 and 2915, which are strategically located near significant discoveries.
– Regional Activity: Recent successful discoveries in nearby blocks, such as Galp’s Mopane, enhance the exploration potential of PEL 79.

By strategically acquiring a stake in Giraffe Energy, Sintana Energy positions itself to leverage recent advancements and discoveries in Namibia’s Orange Basin, potentially unlocking significant new resources and driving further growth in this emerging oil frontier.

Westwood Report: High Impact Exploration Discovery Sizes Halved, Costs Up Sixfold Since 2019

Westwood Global Energy Group’s latest report highlights a significant decline in average discovery sizes and a notable increase in finding costs in high impact exploration. From 2019 to 2023, the average discovery size dropped from nearly 500 million barrels of oil equivalent (mmboe) to approximately 220 mmboe. Concurrently, finding costs have surged sixfold, reaching $1.2 per barrel of oil equivalent (boe).

Factors Influencing the Decline

Several factors contribute to these trends:

  1. Energy Transition Strategies: Companies are prioritizing renewable energy investments over traditional oil and gas exploration.
  2. Industry Consolidation: Mergers and acquisitions have reduced the number of active exploration companies, leading to fewer exploratory drills.
  3. Rising Well Costs: Increased operational costs make new exploration ventures less financially viable.
  4. Reduced Activity in Former Hotspots: Regions previously known for high exploration success are seeing decreased activity due to resource depletion and geopolitical risks.

Success Rates and Company Participation

 Commercial Success Rates.

The commercial success rate of high impact exploration has declined by seven percentage points, reaching its lowest since 2018. Frontier play success rates have stabilized at below 10%, reflecting the inherent risks of exploring uncharted territories.

Participation and Leadership.

The number of companies engaged in high impact drilling dropped from 99 in 2019 to 68 in 2023. Supermajors and National Oil Companies (NOCs) dominate this space, holding about 60% of well equity and leading in resource discovery and commercial success rates.

 Optimism Amidst Challenges.

 Promising Discoveries

Despite the overall decline, recent discoveries, such as those in Namibia’s Orange Basin, indicate that significant hydrocarbon volumes remain untapped. Additionally, the average cycle time from discovery to production has decreased, with oil projects reaching production a year faster than gas projects.

 Changing Dynamics in Exploration.

Graeme Bagley, Head of Global Exploration and Appraisal at Westwood, notes a decoupling of exploration drilling from previous oil prices. High oil prices no longer automatically drive increased drilling activity. Instead, energy transition strategies and industry consolidation are reshaping how companies approach reserve replenishment.

 Comparative Analysis with Renewable Energy Investments.

The shift in exploration dynamics mirrors broader energy trends. Investment in renewable energy has surged, driven by global efforts to combat climate change. Companies like BP and Shell have announced ambitious plans to achieve net-zero emissions, influencing their exploration strategies. This pivot impacts high impact exploration as resources are redirected towards sustainable energy projects.

 Technological Innovations and Their Impact.

Advancements in technology, such as AI and machine learning, are revolutionizing exploration techniques. These technologies improve the accuracy of geological surveys and reduce the time and cost associated with exploratory drilling. As these innovations become more widespread, they may mitigate some of the increased finding costs highlighted in Westwood’s report.


Westwood’s report provides a comprehensive overview of the current state of high impact exploration, highlighting key challenges and emerging trends. The decline in discovery sizes and increased finding costs reflect broader industry shifts towards renewable energy and more efficient, consolidated operations.

While the landscape is changing, significant opportunities remain, underscored by recent discoveries and technological advancements. This dynamic environment demands strategic adaptation from energy companies to balance traditional exploration with the transition to a more sustainable energy future.

Analysis of Factors Influencing the Cost of Building a Petrol Station in Tanzania

The cost of building a petrol station in Tanzania is influenced by various factors that impact both initial investment and ongoing operational expenses.

Understanding these factors is crucial for stakeholders considering entering this market.

Location Impact:

One of the most significant factors affecting the cost of building a petrol station in Tanzania is its location. Urban areas require larger initial investments due to higher land costs and stricter infrastructure requirements compared to rural areas. Urban petrol stations also need to comply with more stringent safety and environmental standards, further adding to costs.

Size and Design Considerations:

The size and design of the petrol station are critical. Larger stations with more pumps and storage tanks have higher construction and maintenance costs than smaller, simpler stations. This is due to the increased materials and labor required for construction, as well as higher operational expenses.

Equipment and Machinery Costs:

Specialized equipment such as fuel storage tanks, pumps, and forecourt canopies constitute a significant portion of the startup budget.

The quality and type of equipment can also impact operational efficiency and maintenance costs over time.

Regulatory Requirements:

Navigating regulatory requirements is another essential factor. Obtaining the necessary licenses and permits from local authorities incurs costs, as does ensuring compliance with safety and environmental standards. These costs should be carefully factored into the budget.

 Land Costs:

The price of land varies significantly between rural and urban areas in Tanzania. Urban areas typically require higher investments due to higher land costs and more stringent regulatory requirements.

Rural areas, while cheaper, may present challenges related to accessibility and infrastructure.

Operational Expenses:

Beyond construction costs, ongoing operational expenses must be considered. These include staffing, utilities, ongoing maintenance, and compliance with safety and environmental regulations. These recurrent costs contribute to the overall cost of operating a petrol station.


In conclusion, the cost of building a petrol station in Tanzania is influenced by a complex interplay of factors ranging from location and size to regulatory requirements and operational expenses. Stakeholders should conduct thorough feasibility studies and cost analyses to ensure they accurately budget for both the initial investment and ongoing costs associated with operating a petrol station.

This analysis aims to provide a comprehensive understanding of the factors impacting petrol station construction costs in Tanzania, equipping stakeholders with the necessary insights to make informed decisions.

Tanzania vs. Mozambique: A Comparative Analysis of Major LNG Investments and Their Regional Impacts

1.Investment Scale


– Estimated Cost: $42 billion

– Significance: One of the largest energy projects in eastern and southern Africa.


– Total Investment: Not fully disclosed

– Major Projects:

– Total-led Area 1: ~$20 billion

– ExxonMobil’s Rovuma LNG: ~$15 billion


Tanzania’s LNG project is notably larger in financial terms, indicating a more substantial investment in infrastructure and long-term energy production capabilities.

This size and scale may attract more international attention and investment, potentially boosting Tanzania’s economy significantly.

2.Production Capacity


– Aim: 10 million metric tons per annum (mtpa)

– Key Players: Equinor, Shell, ExxonMobil


– Total-led Area 1: 6.5 mtpa

– ExxonMobil-led Rovuma LNG: 12.5 mtpa

– Combined Capacity: 19 mtpa


While Tanzania’s individual project is larger, Mozambique’s combined projects exceed Tanzania’s production capacity. This indicates a broader base of operations and a potentially more diversified energy output in Mozambique.



– Final Investment Decision (FID): 2028

– Construction Duration: 3.5 to 5 years


– Area 1 Project:

– Commercial Operations Start: 2027 or 2028

– Rovuma LNG Project:

– FID: 2025


Mozambique’s projects are slightly ahead in their timelines, with one project expected to be operational around the same time Tanzania makes its final investment decision. This head start could provide Mozambique with an early mover advantage in the LNG market.

Strategic Insights.

– Economic Impact: The sheer scale of Tanzania’s project suggests a potentially larger economic impact if successfully executed, possibly creating more jobs and infrastructure development.

– Regional Influence: Tanzania’s project, being one of the largest in the region, could elevate its status as a major player in the energy sector. Mozambique, however, with its multiple projects, showcases a strong and diversified LNG portfolio, potentially making it a resilient energy producer.

– Market Dynamics: Tanzania’s later timeline might align with future market demands better, possibly securing higher prices or better contracts due to anticipated global energy needs.

Key Updates.

– Geopolitical Shifts: Any changes in regional stability, international sanctions, or trade agreements could affect the timelines and investment flows into these projects.

– Technological Advancements:  Improvements in LNG extraction and processing technologies might reduce costs or increase efficiency, impacting overall project economics.

– Environmental Considerations: Increasing global focus on sustainable energy might pressure both countries to adopt greener technologies or face international scrutiny, influencing project viability.


Tanzania’s LNG project stands out due to its massive investment and singular production capacity. In contrast, Mozambique’s combined projects offer higher total output and a head start in operations.


Both countries’ projects are poised to significantly impact their economies and the regional energy landscape, but they will need to navigate geopolitical, technological, and environmental challenges to realize their full potential.


Analysis of the GFPSO Vessel Arrives at GTA LNG Project, Marking Key Milestone for bp

Arrival of the FPSO Vessel.

The recent arrival of the Floating Production Storage and Offloading (FPSO) vessel at the Greater Tortue Ahmeyim (GTA) Phase 1 LNG development marks a significant milestone in the energy project offshore Mauritania and Senegal. This development represents a substantial step forward in bp’s strategy to deliver resilient hydrocarbons.

Project Overview.

– Location and Partners: The GTA project is situated 40 km offshore on the maritime border of Mauritania and Senegal, in a water depth of 120 meters. The project is operated by bp in collaboration with Kosmos Energy, PETROSEN, and SMH.

– Journey and Construction: The FPSO vessel, constructed at the COSCO Qidong Shipyard in China, traveled over 12,000 nautical miles to reach its destination.

– Technical Specifications: The FPSO, with an area equivalent to two football fields and a height of ten storeys, will house up to 140 personnel. It features over 81,000 tonnes of steel, 37,000 meters of pipe spools, and 1.52 million meters of cable.

Strategic Importance and Future Prospects.

– Energy Production: The GTA Phase 1 development is expected to produce approximately 2.3 million tonnes of LNG annually for over 20 years. The project is the deepest subsea infrastructure in Africa, with wells located in water depths up to 2,850 meters.

 – National Significance: The project has been designated as a National Project of Strategic Importance by the Presidents of both Mauritania and Senegal, emphasizing its critical role in the region’s energy infrastructure.

Technical and Operational Aspects

– Processing Capability: The FPSO will process over 500 million standard cubic feet of gas per day, removing water, condensate, and impurities before transferring the gas via pipeline to the Floating Liquified Natural Gas (FLNG) vessel at the Hub Terminal, approximately 10 km offshore.

– LNG Export: At the FLNG vessel, the gas will be cryogenically cooled, liquefied, stored, and eventually transferred to LNG carriers for export. A portion of the gas will be allocated to meet local energy needs.

Broader Context and Implications.

– Energy Transition: This project highlights bp’s dual commitment to current energy demands and future energy solutions, reflecting a balance between traditional hydrocarbons and innovative LNG developments.

– Economic and Environmental Impact: The GTA project is poised to significantly impact the local economies of Mauritania and Senegal through job creation, technological advancement, and energy supply. Additionally, LNG, as a cleaner-burning fossil fuel, offers environmental benefits over coal and oil, supporting global efforts to reduce greenhouse gas emissions.

– Global Energy Markets: The development underscores the increasing importance of Africa in the global energy landscape, with new basins like GTA becoming crucial sources of LNG, catering to rising global demand.

Key Updates and Future Directions.

– First Gas Timeline: The focus now shifts to the safe completion of the project and the commencement of gas production, which will be a critical milestone for the partners involved.

– Potential Expansion: As the first phase of the GTA project progresses, future phases could further enhance production capacity and economic benefits, potentially positioning Mauritania and Senegal as key players in the global LNG market.


The arrival of the FPSO vessel at the GTA Phase 1 development is a landmark achievement that reinforces bp’s commitment to innovative energy solutions. This project not only promises significant economic and energy benefits for Mauritania and Senegal but also highlights the strategic importance of LNG in the global energy transition.

As the project moves towards the production phase, its success will be closely watched by stakeholders worldwide, eager to see its impact on the regional and global energy landscape.

Article source

Eco Atlantic Acquires 75% Stake in Block 1, Expands Presence in Orange Basin Offshore South Africa


 Eco Atlantic Oil & Gas Ltd. has announced its acquisition of a 75% working interest in Block 1 Offshore in the Orange Basin, South Africa. This strategic move involves acquiring rights from Tosaco Energy and becoming the operator of the block, with Tosaco transferring its remaining 25% interest to a new South African entity, OrangeBasin Oil and Gas.

Key Details of the Acquisition

– Location and Size: Block 1 covers nearly 20,000 km² and is situated at the South Africa-Namibia border, extending 263 km into deep water.

– Financial Terms: The acquisition involves payments totaling $750,000 upon different milestones and an additional $2.3 million budget for the first three years’ work program.

– Seismic Data: Existing 2D and 3D seismic data will be analyzed, with no immediate plans for additional seismic acquisition or drilling.

Strategic Importance.

Orange Basin Potential: The Orange Basin is emerging as a significant oil and gas play globally, with substantial potential for both resources. The block’s proximity to known discoveries, such as Shell’s Graff and Galp’s Mopane, increases its strategic value.

Eco Atlantic’s Portfolio: By acquiring Block 1, Eco Atlantic enhances its portfolio, particularly after relinquishing Block 2B. The focus now includes high-potential areas in Namibia, Block 3B/4B, and Guyana, aligning with the company’s strategic objectives.

Comparative Insights.

Guyana and Orange Basin: Eco Atlantic draws parallels between its successful operations in Guyana and the opportunities in the Orange Basin. Both regions show promising statistics, suggesting that the company’s experience in Guyana could translate well to its new ventures.

Regional Discoveries: The presence of inboard gas discoveries (e.g., Kudu and Ibhubesi fields) and significant oil finds to the north and south of Block 1 underscores the region’s potential. These discoveries suggest that Block 1 could also yield significant resources, supporting Eco Atlantic’s strategic expansion.

Key Updates and Future Prospects.

Environmental and Regulatory Approvals: The acquisition and subsequent activities are subject to governmental approvals. No immediate field activities requiring environmental permits are planned, indicating a cautious and compliant approach.

Work Program Focus: Over the next three years, Eco Atlantic will focus on interpreting existing seismic data and planning further exploration. This approach minimizes immediate risks while laying the groundwork for future drilling and resource extraction.


Eco Atlantic’s acquisition of Block 1 Offshore in the Orange Basin represents a strategic expansion into a highly prospective area. The financial and operational terms of the farm-in are manageable, and the existing seismic data provides a strong foundation for future exploration.

By consolidating its interests and focusing on high-potential blocks, Eco Atlantic positions itself for significant growth in the oil and gas sector. This move, while cautious, shows a calculated risk aligned with the company’s broader strategic goals in high-potential offshore regions.


Uplifting Reserves: BW Energy’s Success Offshore Gabon.

BW Energy, an oil and gas exploration and production company listed in Oslo, has reported a significant increase in recoverable reserves at a field within the Dussafu license off the coast of Gabon.

This boost follows the drilling and logging of a pilot appraisal well with a jack-up rig owned by Borr Drilling, an offshore drilling contractor.

Understanding the Findings:

The discovery of oil on the northern flank of the Hibiscus field led BW Energy to conclude the drilling and logging of the DHIBM-7P pilot well.

This process confirmed a substantial oil discovery with good reservoir quality, resulting in a significant uplift to the Hibiscus area. The targeted area is approximately 1.5 kilometers north-northwest of the MaBoMo production platform.

Geological Significance:

The hydrocarbon column, spanning the boundary between the Gamba and Dentale formations, is believed to be the first example of a common Gamba-Dentale hydrocarbon accumulation in the Hibiscus field. This finding holds geological importance and enhances the understanding of the field’s structure.

Reserve Expansion:

BW Energy’s preliminary evaluation suggests an increase in the Hibiscus gross recoverable mid-case reserves by approximately 8 to 12 million barrels of oil. This substantial addition prompts the firm to plan the completion of the well as a development one this year, indicating confidence in the project’s viability.

Operational Update:

Current operations in the Dussafu region include the completion of the DHBSM-2H development well in the northern flank of the Hibiscus South field. This recent appraisal confirmed significant hydrocarbon reserves in the Gamba formation, reinforcing the project’s potential for further development.

Partnership Dynamics:

While BW Energy holds a 73.5% interest in the Dussafu permit offshore Gabon, Panoro Energy holds the remaining 17.5% participating interest. The collaborative efforts between these entities underscore the shared commitment to the Hibiscus/Ruche development project, which targets fields offshore Gabon.

Infrastructure and Logistics:

Oil produced at the project is transported via pipeline to the FPSO BW Adolo for processing and storage before being offloaded to export tankers. This logistical framework ensures efficient operations and facilitates the export of oil from the region.

Expanding Perspectives:

This success story in offshore Gabon not only signifies a significant uplift in recoverable reserves for BW Energy but also holds broader implications for the oil and gas industry in the region. The discovery sheds light on the geological potential of the area, encouraging further exploration and development efforts.

Connecting the Dots:

This development aligns with recent trends in the African oil and gas sector, where substantial discoveries contribute to the region’s economic growth and energy security. The collaborative nature of the project highlights the importance of strategic partnerships in unlocking the full potential of offshore resources.

Looking Ahead:

As BW Energy moves forward with its development plans, stakeholders in the energy sector will closely monitor the progress and implications of this discovery. The successful exploitation of these reserves has the potential to not only benefit the companies involved but also contribute to the socioeconomic development of Gabon and the wider region.