EmPulse® multi-barrier integrity diagnostics system successfully tested on 28% chromium tubulars, ensuring asset integrity and better well performance in challenging production environments TGT Oilfield Services, the market leader in through-barrier diagnostic systems, has announced the successful validation of its electromagnetic EmPulse® well inspection system in high chromium tubulars.   In three Middle East deployments – one an operator witnessed ‘yard test’ and the other in two live wells – TGT engineers demonstrated that the EmPulse system can quantitatively determine the individual tubular thickness of up to four concentric barriers, even when there are high amounts of chrome in the tubulars.   Ken Feather, TGT’s chief marketing officer commented, “This achievement marks an important industry breakthrough as operators endeavour to protect well integrity in ever more challenging production environments. Increasing chromium content helps to protect well completions from highly-corrosive fluids, such as carbon dioxide, hydrogen sulphide and chloride—but high-chrome can cause serious problems for ordinary electromagnetic pipe inspection systems.”   He continues, “It’s essential that operators can access integrity inspection systems that work reliably and accurately throughout the well system in all environments and materials, especially where corrosive and toxic fluids are involved. This is why we created the EmPulse diagnostic platform.”   The increase in chrome and the resulting decrease in ferrous content causes electromagnetic [EM] signals to decay too quickly for ordinary EM inspection systems. Designed and manufactured completely in-house by TGT scientists and engineers, the EmPulse system combines ultra-fast sensor technology with ‘time-domain’ measurement techniques to capture EM signals rapidly and accurately in a wide range of pipe materials, including those with high-chrome content. This enables operators to evaluate pipe thickness and metal loss in multiple casing strings simultaneously, ensuring long-term well performance even in the most challenging production environments. Pulse characterisation lab, Technology Centre “The ability of EmPulse technology to make measurements when facing specialised materials in certain well tubulars marks a significant breakthrough for TGT and the industry as a whole,” said Simon Sparke, TGT integrity expert and coordinator of the high-chrome testing programme.   “That’s why today’s test results are so important, demonstrating how the EmPulse system of sensors, measuring techniques, processing and answer products can deliver fast response corrosion information, address a crucial information gap, and help protect well integrity in challenging production environments. We anticipate that EmPulse will be particularly applicable for the Middle East operators, and also some fields in the Gulf of Mexico, the North Sea and offshore Brazil.”   TGT’s EmPulse technology adds considerably to the integrity security of a well by providing barrier-by-barrier visualisation of the well operating envelope at the time of logging. The time-based measurements, enabling the system to quantify metal loss in up to four barriers independently and deliver highly sensitive and fast response measurements, brings with it significant advantages over frequency-based measurements offered by other systems. The Middle East operator witnessed ‘yard test’ consisted of a 28% chrome pipe with built-in mechanical defects where the high-speed EM sensor technology of EmPulse confirmed and correctly identified the man-made problems in a controlled environment.   The second operation took place in two live Middle East wells in a very high hydrogen sulphide gas production scenario with 28% chrome tubulars. In this case, the EmPulse system again functioned as planned, and recorded the status of three well barriers. Additionally, a multi-finger caliper recording confirmed the electromagnetic results for the condition of the inner pipe.

EmPulse® multi-barrier integrity diagnostics system successfully tested on 28% chromium tubulars, ensuring asset integrity and better well performance in challenging production environments. TGT Oilfield Services, the market leader in through-barrier diagnostic systems, has announced the successful validation of its electromagnetic EmPulse® well inspection system in high chromium tubulars.   In three Middle East deployments – one an operator witnessed ‘yard test’ and the other in two live wells – TGT engineers demonstrated that the EmPulse system can quantitatively determine the individual tubular thickness of up to four concentric barriers, even when there are high amounts of chrome in the tubulars.   Ken Feather, TGT’s chief marketing officer commented, “This achievement marks an important industry breakthrough as operators endeavour to protect well integrity in ever more challenging production environments. Increasing chromium content helps to protect well completions from highly-corrosive fluids, such as carbon dioxide, hydrogen sulphide and chloride—but high-chrome can cause serious problems for ordinary electromagnetic pipe inspection systems.”   He continues, “It’s essential that operators can access integrity inspection systems that work reliably and accurately throughout the well system in all environments and materials, especially where corrosive and toxic fluids are involved. This is why we created the EmPulse diagnostic platform.”   The increase in chrome and the resulting decrease in ferrous content causes electromagnetic [EM] signals to decay too quickly for ordinary EM inspection systems. Designed and manufactured completely in-house by TGT scientists and engineers, the EmPulse system combines ultra-fast sensor technology with ‘time-domain’ measurement techniques to capture EM signals rapidly and accurately in a wide range of pipe materials, including those with high-chrome content. This enables operators to evaluate pipe thickness and metal loss in multiple casing strings simultaneously, ensuring long-term well performance even in the most challenging production environments. ElectromagneticCalibration “The ability of EmPulse technology to make measurements when facing specialised materials in certain well tubulars marks a significant breakthrough for TGT and the industry as a whole,” said Simon Sparke, TGT integrity expert and coordinator of the high-chrome testing programme.   “That’s why today’s test results are so important, demonstrating how the EmPulse system of sensors, measuring techniques, processing and answer products can deliver fast response corrosion information, address a crucial information gap, and help protect well integrity in challenging production environments. We anticipate that EmPulse will be particularly applicable for the Middle East operators, and also some fields in the Gulf of Mexico, the North Sea and offshore Brazil.”   TGT’s EmPulse technology adds considerably to the integrity security of a well by providing barrier-by-barrier visualisation of the well operating envelope at the time of logging. The time-based measurements, enabling the system to quantify metal loss in up to four barriers independently and deliver highly sensitive and fast response measurements, brings with it significant advantages over frequency-based measurements offered by other systems.

Dubai, U.A.E – 18th December 2023   TGT announced today that it has successfully achieved the first batch assembly of their diagnostic technology in the UAE. This milestone is part of TGT’s major investment in a new technology hub slated for opening in Khalifa Economic Zones early 2024.   Commenting on the development, TGT’s chairman and CEO, Saad Bargach said, “This is an important step in our ongoing commitment to manufacture within the UAE from 2024 onwards, as we expect to complete our new UAE Technology Hub and secure our “Made in UAE” commercial license within the next few months. Implementing these flagship resources within the UAE reflects our commitment to the UAE and the Middle East region, and to diversifying our business internationally so we can serve our clients better. We are particularly looking forward to establishing collaborative research and commercial projects with local universities and energy companies.”   TGT has already begun construction of its new UAE Technology Hub under an agreement with the Khalifa Economic Zones Abu Dhabi KEZAD Group, after announcing its intentions to invest in the region earlier this year. The new technology hub will be home to TGT’s scientific and engineering resources, research and development, information technology, software and AI development, manufacturing, maintenance, quality assurance, and headquarter functions.   The first batch of diagnostic equipment assembled in UAE has been fully tested and delivered for use within TGT’s regional business units. The company has had a hugely successful 2023 and has an order book for significant volumes of new diagnostic systems to serve further demand increases in 2024 and beyond. About TGT Diagnostics      TGT creates powerful diagnostic systems that are essential to the delivery of hydrocarbons and energy. Oil and gas producers globally rely on TGT’s diagnostic insights and expertise to help them decarbonise their operations and keep wells safe, clean, and productive.   TGT’s diagnostic systems are organised in two domains, True Flow and True Integrity, each aimed at diagnosing flow and integrity dynamics throughout the entire well-reservoir system. Headquartered in Dubai, UAE, the company employs ~350 analysts, engineers, scientists, and support staff, with offices and global operations in Africa, North & South America, Asia, Europe, UK, and the Middle East.

Dubai, UAE – 24 May 2023   TGT announced today that its ‘Horizontal Flow powered by Cascade3 brand strategy and brand campaign won Gold for “Best visual identity from the energy and utilities sector” , as well as ‘highly commended’ in two other categories for 'Best Development of a New Brand Within an Existing Brand Portfolio' and 'Best Strategic or Creative Development of a New Brand', at the tenth annual Transform Awards MEA 2023.   This is the third cluster of brand accolades TGT received from the Transform awards, following its previous Gold and Silver success for the total brand transformation of its ‘TGT Diagnostics’ parent brand and Pulse1 brand strategy.   This is a tremendous achievement for the company and a credit to our talented brand team”, commented Ken Feather, Chief Marketing Officer, TGT. “We engineered and produced all aspects of the Horizontal Flow powered by Cascade3 brand, from consumer research to positioning, developing brand codes, sales collateral, media content and executing an ambitious communications campaign #KnowYourFlow. To win alongside so many iconic brands and professional brand agencies is an outstanding result. I’m very proud of the team”, continued Ken.   Horizontal Flow powered by Cascade3 technology delivers accurate assessments of flow dynamics in horizontal wells, enabling asset teams to manage well and reservoir performance more effectively, helping energy producers keep wells safe, clean and productive.   “Horizontal wells promise enormous efficiency and economic gains but are notoriously challenging to manage. Horizontal Flow with Cascade3 solves many of the diagnostic challenges faced by Reservoir and Production Engineers, providing them with the insights they need to reduce operating costs and energy consumption and increase ultimate recovery.” added Ken. Established in 2009, the annual Transform Awards recognise the most innovative, creative and successful brand work across the world. Covering seven regions, this prestigious awards programme focuses on specific aspects of the branding process and provides a platform to benchmark and showcase exemplary work in brand strategy and development.   Andrew Thomas, publishing editor of Transform magazine and founder of the Transform Awards, says, “For the past 10 years, the Transform Awards has benchmarked the best of brand strategy, creativity and design in the Middle East and Africa region. Tonight’s ceremony truly demonstrated the transformative power of brand strategy and design, and we look forward to carrying on these celebrations over the next decade.   TGT continues to focus on providing diagnostic solutions that help the oil and gas industry reduce emissions and achieve carbon-zero targets, enabling a sustainable energy future for everyone. Transform Awards MEA 2023 winners

Abu Dhabi, U.A.E – 17th May 2023   TGT Diagnostics today announced it has signed an agreement to build a new Technology Hub in Abu Dhabi. The category leader in diagnostics for the hydrocarbon energy sector said it will make a significant investment in a new state-of-the-art facility under an agreement with Khalifa Economic Zones Abu Dhabi KEZAD Group.   The new UAE facility is a major investment for TGT as it moves to strengthen its ties with customers and partners in the Gulf region and beyond. With the aim of being fully functional by year end, the new technology hub will be home to TGT’s scientific and engineering resources, research and development, information technology, software and AI development, manufacturing, maintenance, quality assurance, and headquarter functions.   Saad Bargach, TGT’s Chief Executive Officer commented, “At TGT, we provide essential diagnostics that help our customers keep wells safe, clean, and productive. Our new technology hub will, for the first time, bring together our R&D, engineering, manufacturing, and corporate functions under one roof. This will enable several synergies and provide the perfect platform for future growth. With growth plans in mind, we will recruit and develop the best talent at all levels of the organisation and continue to develop the category-leading diagnostic systems we are famous for.”   As well as expanding TGT’s network in the region, the new high-tech manufacturing centre within the hub will enable the company to meet the ever-growing demand for its unique diagnostic systems and products across the Americas, Asia, Europe, Africa, and the Middle East. The company is on target to launch its first full production series of UAE-made diagnostic systems by 2024. About Us   TGT Diagnostics creates powerful diagnostics that are essential to the delivery of hydrocarbons and energy. Oil and gas producers globally rely on TGT’s technology and products to help them decarbonise their operations and keep wells safe, clean, and productive. The company is headquartered in the UAE and has offices and operations in multiple locations including Africa, North & South America, Asia, Europe, and the Middle East.

"Horizontal wells can be both challenging and rewarding." Article featured in Oil Review Middle East (article link)   Managing their performance is a complex task for petroleum engineers and asset teams. But, with the right strategies in place, a horizontal well will usually deliver much higher levels of productivity than could be achieved with a vertical well. TGT’s new Horizontal Flow diagnostics technology has been designed to assess flow in horizontal wells and to deliver a clearer picture of well-system behaviour.     Flow inside the wellbore of a horizontal well can be challenging to decipher, but flow outside is even more complex, and way beyond the reach of conventional production logging (PL) surveys. For years, petroleum engineers have been searching for better survey options in horizontal wells and for systems that could deliver continuous flow profiles across different completion and reservoir scenarios. TGT has addressed these needs with its Horizontal Flow product, an advanced flow-diagnostics resource powered by Cascade3 technology.     This innovative technology features a powerful modelling and simulation engine that predicts the hydrodynamic and thermodynamic behaviour of fluids and their surroundings as those fluids flow through the well-reservoir system. Horizontal Flow is specifically designed for use in horizontal wells and, using the industry’s most advanced hydrodynamic and thermodynamic modelling technologies, it can translate temperature, pressure, and other well-system data into continuous reservoir flow profiles.     These profiles deliver a true picture of inflow and outflow even in challenging wells, such as those with natural or hydraulically induced fractures. The new technology evaluates the common types of flow pattern encountered in horizontal well systems (radial, spherical and linear/fracture), thereby making it possible to assess the linear flow occurring in fractures and to determine fracture contribution. This is particularly useful when combined with the Chorus acoustic sensing system that identifies fracture locations.     Horizontal Flow helps asset teams: • establish reliable, continuous flow profiles • locate water or gas breakthroughs • reduce carbon per barrel • maintain a more accurate reservoir model • measure effective pay length • make more accurate reserves assessments • reveal crossflow problems • evaluate the performance of inflow control devices and packers • assess fractures • make more accurate production forecasts • optimise completion designs.     Production engineers, reservoir engineers and the wider asset team need to ensure that each well system performs to expectations by achieving production targets and maximising recovery. Effective management of horizontal wells can deliver huge production benefits. TGT’s new Horizontal Flow diagnostics technology offers clearer insights and helps keep well and reservoir performance on track.

Challenge High water cut in producing wells leads to unnecessarily high carbon dioxide emissions and increased carbon-per-barrel rates. Managing, treating, and reinjecting or disposing of excess water requires large amounts of energy, making water cut reduction a key area for performance improvement. Well OP-1 was completed in 1971 as a vertical oil producer and it features a large number of perforated zones from numerous campaigns over the course of its operational history. The oil production rate was approximately 100 bpd, which was considered uneconomic, and the operators decided to switch the completion zone to boost production and enhance recovery from the field.   Following a workover in December 2018, the well was put back on production from the new completion zone (B2), but unexpected water production was observed. The total liquid rate was more than twice the projected level and the water cut was about 80%. The production gas–oil ratio at the separator was lower than expected when compared with a PVT analysis of the B2 zone in a nearby well. Furthermore, water analysis results for well OP-1 were close to the existing results from other completion zones, which indicated substantial water entry from an unknown source. Figure 1: Pre-workover diagnostics survey reveals that the main source of water is non- perforated water-bearing Zone B1. Solution Conventional production logging tools such as spinner and multiphase sensors can provide a production profile inside the wellbore, but cannot identify behind-casing communication with water-bearing formations or crossflow.   The field operator selected TGT’s Total Flow diagnostics to determine whether behind-casing crossflow was the cause of high water cut in well OP-1 and to locate the water source. The combination of TGT’s Chorus spectral acoustic survey with standard production logging tools enabled the survey team to identify behind-casing flow (Figure 1). TGT’s Indigo and Cascade technology was also used to quantify the low flow rates. Figure 2: Post-workover survey confirms the effectiveness of the remedial work and the elimination of water entry from Zone B1. Result Analysis of the survey results indicated that the crossflow from the previously isolated perforated zones was less than 1% of the total. About 30% of the liquid inflow was coming from the targeted perforated interval (Zone B2). The main unwanted production (approximately 69%) was coming from the non-perforated water-bearing Zone B1 and was the result of behind-casing crossflow (Figure 2). A remedial workover was conducted in September 2019 to address the crossflow issue. A cement evaluation log showed that the cement condition above the Zone B2 perforation interval was improved and a successful pressure test (3,000 psig) against Zone B2 was performed. The productive Zone B2 was stimulated once more using a revised procedure.   A flowback test conducted before the second survey showed that there had been a significant decrease in water production with time, and water cut was 0% in the post-workover survey. Both Chorus and Indigo data analysis confirmed that inflow was from only the targeted interval with no evidence of behind-casing communication with Zone B1 (Figure 3).   TGT’s True Flow enabled the field operator to identify the water source and shut it off, thereby increasing oil production, lowering carbon intensity and improving well economics

Go with the flow Article featured in Oilfield Technology's 2022 summer magazine (pages 42-45)   As the global energy mix transitions to low-carbon sources, there may be fewer opportunities for new oil and gas field developments. As a result, many operators will shift their focus towards recovering more from existing reservoirs, and this strategy includes improving the management and performance of their Horizontal wells.   Horizontal wells generally deliver much higher levels of productivity than their vertical counterparts, but this performance can often come at a cost. Understanding the interactions between a horizontal well and the reservoir can be extremely challenging. The combination of variable well angles, extended reservoir contacts, the presence of fluid mixtures and segregated flows, formation changes, fractures and intricate completions presents a formidable challenge for analysis using conventional production-logging tools (Figure 1).   Standard production-logging technology may, under some conditions, be able to map the multiphase flows encountered in a horizontal wellbore, but it cannot quantify flows for fluids exiting or entering the reservoir behind the completion. This means that wellbore production logs do not provide a complete picture of flow dynamics across the well system. Asset teams that base development, production or remediation plans on an incomplete partial flow diagnosis may be risking lower productivity, reduced asset performance, and higher carbon overhead.   A new beginning Reservoir and production engineers have been looking to overcome the drawbacks of conventional production surveys in horizontal wells for many years. Their key requirement has been a system that could deliver continuous flow profiles across different completion and reservoir scenarios, and would also be effective in reservoirs with fractured formations.   TGT Diagnostics has been working on addressing these needs for several years and, in February 2022, launched the Horizontal Flow diagnostics product with Cascade3 technology. Specifically designed for horizontal wells, this system offers more realistic flow modelling and accurate continuous flow profiles in a wide variety of completion and reservoir settings. The insights gained from this have the potential to help companies reduce operating costs and energy consumption while increasing ultimate recovery.   The new technology uses an advanced modelling simulation engine to predict the hydrodynamic and thermodynamic behaviour of fluids and their surroundings as they flow through the well-reservoir system. This translates temperature, pressure and other well-system data into continuous reservoir flow profiles. These profiles deliver a true picture of inflow and outflow, and this is the case even for challenging wells and those that feature natural or hydraulically induced fractures.   The ability to assess flow in fractured reservoirs is important because, although fractures can boost hydrocarbon production, they can also provide pathways for early water or gas breakthrough. The new diagnostics technology can evaluate the radial, spherical and linear/fracture flow patterns commonly encountered in horizontal well systems (Figure 2). This provides an accurate assessment of linear flow occurring in the fractures and makes it possible to determine the fracture contribution. This is particularly useful when combined with the Chorus acoustic sensing system that identifies fracture locations along the wellbore.   Applications and benefits Operating companies want to maximise hydrocarbon recovery in the safest, cleanest and most economical way possible. Having an accurate picture of fluid flow in the wellbore and the immediately surrounding reservoir rock gives asset teams greater confidence in their decisions and makes it easier to enhance production, maximise recovery and rectify well problems.   The new diagnostics system provides useful input in key areas such as reservoir, well and resource management, and can even help companies enhance their environmental performance and reduce the carbon footprint of production operations.   Insights for reservoir management Effective reservoir management is a key objective for oil and gas operating companies. The development of any hydrocarbon reservoir disturbs a natural balance of rocks and fluids that may have existed for millions of years. Understanding how a reservoir will behave as new wells are drilled and fluids are extracted or injected is a daunting task. Reservoir engineers deal with huge uncertainties in their quest to maximise hydrocarbon recovery, reduce operating costs and extend the economic life of the reservoir.   At the heart of the reservoir-management process is the dynamic reservoir model, which provides a basis for all field development and hydrocarbon recovery decisions, infrastructure investments and reserves estimations. The robustness and accuracy of the model is critical to successful reservoir management, and any inaccuracies may lead to poor decisions and substantial losses.   As more data is collected, the dynamic reservoir model is updated by the reservoir engineering team using a process known as history matching. Insights from this new diagnostic system can play a critical role in history-matching, thus helping to reduce the uncertainty envelope and improve the model. A continuous flow profile provides a clear and direct quantification of the flow performance of the reservoir as it feeds the well system. In contrast to standard wellbore production surveys, which can be hindered by completion or reservoir integrity issues, Horizontal Flow can deliver a true flow profile. The continuous nature and sensitivity to low flow rates help provide a more accurate measurement of effective pay length, a key metric for making production forecasts and reserves estimates.   The new system is also effective in the presence of fractures. Predicting and preventing water or gas breakthrough is one of the most important and challenging tasks faced by reservoir engineers. Having a deeper understanding of downhole flow dynamics can help provide an early warning of locations where water or unwanted gas may be reaching the well.   The new workflow can also be used to estimate or validate other key parameters such as reservoir pressure, permeability and skin factor. This independent verification can help reservoir engineers to resolve uncertainties, improve history matching and optimise the dynamic reservoir model. Figure 1. Horziontal Flow leverages Cascade3 and the True Flow system to deliver the truest picture of inflow and outflow downhole, even in the most challenging wells. Figure 2. Flow inside the wellbore of a horizontal well can be challenging to decipher, but flow in the surrounding reservoir is equally complex. New technologies can help resolve all three primary flow patterns that surround the well system - radial, spherical and linear flow in fractures - and combines thermodynamic and hydrodynamic science in an immersive 3D fine grid modelling architecture. The result is accurate reservoir flow profiles and unique insights that help asset teams keep performance on track. A diagnostic approach to well management Horizontal wells are designed to provide optimum contact with the reservoir and so tap hydrocarbon reserves with maximum efficiency. Production engineers in the wider asset team are responsible for the well system and ensuring that it performs to expectations, thereby maintaining production targets and maximising recovery.   Well performance depends under dynamic relationship between the well completion and the reservoir surrounding it. This, in turn, depends on the performance and behaviour of completion components and the reservoir itself. To achieve their technical and business aims, production engineers need full visibility of fluids and flow dynamics downhole from the reservoir sandface to the wellbore and at all points in between. The Horizontal Flow diagnostic system helps to deliver this visibility.   Measuring real production or injection performance in the presence of complex multicomponent completions is a major challenge for production engineers. Integrity issues and zonal isolation or component failures can lead to discrepancies between the profile of fluids entering or exiting the wellbore and the profile of fluids exiting or entering the reservoir. In these situations, standard production logs could give false or misleading results. The new diagnostics system overcomes this by providing a definitive flow profile regardless of completion, integrity or zonal isolation issues. Furthermore, by identifying these issues, it can help guide maintenance or workover interventions. Vicious fluids, fluid segregation and low flow rates can also be problematic for standard production-logging sensors, leading to a false picture of flow. Horizontal Flow incorporates temperature and acoustic measurements that respond to all types of meaningful flow, thereby helping to overcome this limitation.   The new approach can also be used to assess injection compliance and the performance of completion elements such as flow control devices and swell packers. The information gained from these analysis can be used to target repairs and guide potential improvements in completion designs.   Enabling effective resource management Operating companies want to maximise ultimate recovery while minimising operating costs, thereby reducing cost per barrel produced. Horizontal Flow diagnostics can help on both sides of this equation.   Developing a field with horizontal wells represents a significant investment in time, energy and capital. Diagnostics play a key role in tracking well and reservoir performance, and steering asset team decisions. Horizontal Flow diagnostics can reveal well system inefficiencies, guide asset teams to problem areas in the completion or the reservoir, and help them act with greater certainty to achieve a positive outcome.   Horizontal well interventions can be expensive and time-consuming, and often require specialised equipment, such as coiled tubing or tractors, for well access. Diagnostic deployments of the new system can provide a complete and accurate downhole assessment and information that reduces uncertainty and quickly establishes whether remedial work is required. When a workover is deemed necessary, the ability to plan and target it with a greater precision helps save time, reduce costs and deliver better outcomes.   Reducing your environmental impact Operating companies around the world are aiming to cut their carbon-per-barrel overhead. Developing and producing oil and gas consumes enormous amounts of energy from diesel engines or gas turbines, both of which produce significant volumes of carbon dioxide (CO2). Flaring of unwanted associated gas is another major source of emissions. Combined CO2 emissions from global upstream operations are estimated at about 1 Gt CO2 per year and methane emissions at around 1.9 Gt CO2 per year. New diagnostics technology can help operators identify inefficiencies in energy-intensive operations, reduce associated gas flaring and improve the efficiency of energy-intensive intervention operations.   Water injection accounts for approximately 40% of total CO2 emissions in a typical oilfield. Operators can now assess how much of the injected water is reaching its target and identify thief zones. These diagnostic surveys often lead to a reduction in pumped water volumes and emissions, and increased field production. Water production is another source of emissions, as produced water must be managed and treated at the surface. This process requires energy, and increased water production typically means less oil, thus reducing ultimate recovery and increasing carbon per barrel.   Gas flaring is estimated to release 310 MT CO2 per year, which is about 30% of all upstream CO2 emissions. Continuous flow profiles can be used to identify sources of unwanted gas downhole and guide remediation plans, thereby reducing the need to flare.   Workovers and diagnostic interventions in horizontal wells can also have a significant carbon overhead. New diagnostics technology can minimise this overhead on two fronts when compared with the conventional approach.   Firstly, it can easily identify the crossflows, fractures and integrity failures that often confuse conventional surveys. Having this information minimises the risk of incomplete or inaccurate assessments and improves the efficiency of decision-making. Secondly, when equipped with reliable information, the asset team can plan and target its workover programmes with precision. This means equipment and operations can be optimised and executed with higher efficiency and success rates, leading to better technical outcomes and lower emissions.   Conclusion Horizontal wells are powerful tools for hydrocarbon production and represent a significant resource investment for field operators. Production engineers, reservoir engineers and the wider asset team face complex challenges in their drive to ensure that each well system performs to expectations. A new approach to flow analysis in horizontal wells could help to solve key challenges in this area, making it easier for wells and reservoirs to reach their full potential.