Data Insights with bMark™: Trend of the Week

Welcome to the Weekly Data Dive with bMark™ Software! 📊

Dive into the dynamic world of energy trends and environmental insights as we unravel the latest findings from our cutting-edge datasets. Every week, we bring you a captivating journey through the realms of recovery factors, carbon sequestration potential sites, oil recovery dynamics, and beyond.

Screening Carbon Capture & Storage Sites using bMark™ Database

This week’s #TrendoftheWeek comes from bMark™>CCS – our module for visualising global data and screening sites for Carbon Capture and Storage projects.

Last week’s #TrendoftheWeek highlighted the use of different drive mechanisms in hydrocarbon extraction. Here, in blue, we filter the bMark™ subsurface database using the Society of Petroleum Engineers (SPE) criteria for CO2 Enhanced Oil Recovery (EOR) to highlight fields with potential for miscible CO2 injection.

In orange, we can see data for CO2 emission sites in South East Asia sized based on their output (Mtpa). Visualising this spatial trend of CO2 output we can look at where CCS hubs may develop linked to EOR projects.

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Co2 Emissions Map and Potential Storage Site

Maximizing Oil Recovery: Exploring Global Pressure Management Strategies Through Analogues

This week’s #TrendoftheWeek, built from bMark™ data, focuses on the differences around the world in how pressure in oil reservoirs is managed via the reservoir drive mechanism. 

Producing oil efficiently requires management of pressure within the reservoir with the ideal reservoir production pressure typically maintained stable and just above the point at which gas will escape from the oil, known as the bubble point pressure. Determining, predicting and maintaining the optimal pressure conditions for an oil field is a large part of a Reservoir Engineer’s job.

In some basins Operators are lucky enough to have natural pressure support mechanisms such as aquifer influx and gas cap expansion which can help to provide pressure support to balance the loss of pressure from oil extraction however this is not always the case and in many cases without adding additional pressure support to enhance the Natural Drive mechanisms then reservoir pressures will decline and reserves will be lost. 

To support pressures it is common to inject water and/or gas to support pressures artificially, known as secondary drive. In some cases Operators may go beyond secondary drive and add heat, polymers, microbes or chemicals to injected fluids to achieve “tertiary” drive, often also called enhanced oil recovery or EOR.

Application of secondary and tertiary (EOR) drive mechanisms in oil fields increases the reserves recovery of a field but comes with additional operational costs, complexities and technological requirements all of which must be balanced in each case against the incremental reserves recovered. 

Looking at our chart the rest of the world lags North America in application of secondary drive – what reserves uplift potential could there be if this gap was closed?

bMark™ can help Operators understand where analogues to their field have benefited from secondary & tertiary recovery and what application in their field might mean for added reserves.

Stay in the loop with our latest weekly trends and insights! Click here to read this week’s update and explore more.

 

 

Trend of the Week. Maximizing Asset Potential: Insights from bMark™’s Predictive Benchmarking for Enhanced Recovery and Performance

Only with large analogue datasets can we get the best insights. Predictive benchmarking in bMark™ harnesses machine learning to analyse asset performance and enables user to maximise the value of their assets. 

Our Recovery Factor benchmarks combine rock and fluid properties to predict Recovery Factor of fields and reservoirs. bMark™ also includes predictive models for Number of Wells and Peak Rates. These insights can be used at any point of field maturity and in any field in the world. 

In our #trendoftheweek this week we look at the Ghawar in Saudi Arabia, the largest conventional oil field in the world, comparing recovery factor performance against our Global benchmark. Shown in black, at a field level we see good performance with the field narrowly above the bMark™ prediction.

But this only tells a small part of the story…we always encourage users to benchmark their assets at a reservoir or flow-unit level. The orange points represent the reservoir units that make up the field. Whilst 4 of the reservoirs are performing well against their benchmark prediction, there are 2 reservoirs that may have potential for an increase in Recovery Factor and therefore an increase in reserves.

Are you harnessing data-driven insights and maximising the value of your assets?

Discover the power of bMark™ firsthand! Request a demo today to try it yourself and unlock valuable insights for your assets. Contact Us

Ghawar in Saudi Arabia, the largest conventional oil field in the world

Week 5. Celebrating Technological Advancements in Oil and Gas Drilling

This week’s #TrendoftheWeek, built from bMark™ data, celebrates the technological achievements of the drillers in the Oil & Gas Industry with a chart displaying how the boundaries of ‘how deep we can go’ have been continuously pushed back over the course of the 20th and early 21st Centuries. 

Technological advancements have always propelled the oil and gas industry to drill deeper into the Earth’s crust. Innovations in drilling techniques, equipment, materials, telemetry and real-time data analysis have expanded depth capabilities significantly. 

Drilling deeper has become essential as traditional reserves dwindle, prompting the industry to pursue harder-to-reach oil fields. Meeting global energy demands has necessitated accessing these untapped resources, driving the push for innovation.

Despite the complexities and higher costs associated with deeper drilling, the potential rewards in securing future energy supplies make it imperative for the industry to invest in technological advancements continuously. How far will we go in the future?

 

Week 3. Oil & Gas Global Analogues: Ramadan Field Vs Gulf of Suez

In the spirit of Ramadan, let’s shine a light on the Ramadan field, discovered in May 1974 in the Gulf of Suez, Egypt. Harnessing the power of bMark™, we compare the field to its peers in the of Gulf of Suez, a mature province where exploration continues to yield new discoveries.

Here we visualise Porosity vs Permeability data from over 100 fields and reservoirs, extracted from the bMark™ subsurface database. With a porosity of 15%, Ramadan sits just below the mean porosity of 18% observed in the Gulf of Suez. This comprehensive dataset allows for the validation of pre-drill expectations, providing valuable insights into subsurface trends.

Ready to explore the power of bMark™ firsthand? Get in touch with us today to schedule a demo and discover how bMark™ can enhance your workflows with its vast database and powerful insights.

Ramadan Field

 

Week 4. Discovery and First Production

Are we becoming more efficient?

One thing consistently strived towards in the energy industry is efficiency. Both in terms of time and cost. But this can often be a very difficult thing to quantify and prove.

Using the large database in bMark, for offshore fields in the mature North Sea region, we investigated the number of months between discovery and first production of a field. We can see clearly a systematic reduction in this metric through the decades from fields discovered in the 1960s to 2010s, likely driven by improvements in technology, economies of scale and existence of prior infrastructure.

Interestingly, although the mean continues to fall throughout the decades, the spread from upper to lower quartile from discoveries in the 2010s increases comparatively to the 2000s. Could this be a knock on from volatility in markets in the 2010s impacting decision making? 

The slowing of progress in this metric highlights the importance of other efficiency factors such as production technology innovation and development ramp up after first production.

We can use similar trends from basins around the world to benchmark development planning assumptions for future projects, ensuring that forecasts are reasonable and in line with analogues.

Trend of the week

Trend of the week 2: Unveiling the Depths. Insights into Supercritical Carbon Storage with bMark™ CCS

Carbon storage projects typically aim to maintain injected CO2 in a supercritical state, which, for CO2, is achieved at temperatures exceeding 88°F and pressures greater than 1057 psi. In this supercritical state, CO2 displays properties of both a gas and a liquid, sharing the density of a liquid but possessing the viscosity typical of a gas. The primary advantage of storing CO2 in a supercritical state is the substantial reduction in necessary storage volume, allowing for higher storage capacity.

For screening purposes, a top structure depth of 800mTVDss serves as a typical guideline to determine whether a reservoir will have the required pressure and temperature conditions. However, our bMark™ trend of the week reveals that while this guideline is generally reliable, it does not always ensure that a reservoir will fall within the supercritical window.

We have identified over 450 global fields and reservoirs that exceed this depth criteria but are outside the supercritical CCS window. Interestingly, many of these highlighted fields are concentrated in the Volga-Urals region, potentially posing challenges for efficient decarbonization efforts.

Although only around 3% of the total dataset with depths exceeding 800m would be unsuitable, this exercise emphasizes the importance of employing a comprehensive screening workflow, such as those offered by bMark™>CCS, to ensure that specific fields are technically feasible.

Trend of the week 1: Exploring Volume Estimates in the Orange Basin, Namibia

The Orange Basin, Namibia, is a particularly exciting exploration region, following several recent successful discoveries.

But in such an immature basin, can we predict the likely volumes in place?

bMark™ shows the expected range to be from 20-3000MMstb based on a P10-90 range, with the P50 volume of 200MMstb.

The extensive global database available in bMark™ can be used to identify analogous basins, in this case Rifted Passive Margins containing similar aged reservoirs. Volumetric data can then be interrogated to provide a range and distribution of volumes in these basins, which can be linked with other influencing factors, such as water depth, facility type or even Operator.

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    Technical assurance given at Final Investment Decision

    Greenfield oil development offshore Mexico; 1500MMstb in place

    • bMark™ helped identify twelve (12) key producing analogues, in the Gulf of Mexico.
    • Data analytics & benchmarking performed on the reservoir data. Production profiles, recovery factor forecasts & development plan supporting the FID case
    • Insights supported the FID mid-case plan & forecasts, whilst also provided guidance on areas for further modelling & sensitivity analysis.

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