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Decarbonise with diagnostics

Decarbonise with diagnosticsDecarbonise with diagnostics Overview Decarbonise video Greenhouse gas emissions How can TGT help? Applications Go to section OverviewDecarbonise videoGreenhouse gas emissionsHow can TGT help?Applications Home Search Results Global warming, climate change, and hydrocarbons Today, global warming is an existential crisis facing our planet and all of its inhabitants. Climate science tells us that if global average temperatures rise more than 1.5°C above pre-industrial levels, the impact could become catastrophic and irreversible. In the oil and gas industry, we are all aware of the very real impact the climate crisis is having on society and the planet. Whilst we provide energy for the world to prosper, the way most of this energy is produced as well as consumed, is ultimately leading to climate change. Whilst we continue to develop clean energy solutions, the reality is that ~56% of the global energy mix continues to come from hydrocarbons, and it will take years, if not decades, before the balance shifts to cleaner sources. Global warming, climate change, with diagnostics Today, global warming is an existential crisis facing our planet and all of its inhabitants. Climate science tells us that if global average temperatures rise more than 1.5°C above pre-industrial levels, the impact could become catastrophic and irreversible. In the oil and gas industry, we are all aware of the very real impact the climate crisis is having on society and the planet. Whilst we provide energy for the world to prosper, the way most of this energy is produced as well as consumed, is ultimately leading to climate change. Whilst we continue to develop clean energy solutions, the reality is that ~56% of the global energy mix continues to come from hydrocarbons, and it will take years, if not decades, before the balance shifts to cleaner sources. Watch our video to find out moreGreenhouse gas emissions in GtCO2e Every barrel of oil or gas equivalent has a carbon overhead because of the energy consumed to produce it, the flaring of gas, and the leakage or venting of methane from well infrastructure. In 2019, upstream activities released ~2.9 GtCO2e, or ~6% of the total annual greenhouse gases produced by human activity. As suppliers of energy to society, our industry has a vital role to play in taking action today to achieve a low-carbon future. TGT is at the forefront of this with our diagnostics-led sustainability framework. With this, our role is to help oil and gas producers deliver energy through the transition, but with significantly lower environmental impact. Every barrel of oil or gas equivalent has a carbon overhead because of the energy consumed to produce it, the flaring of gas, and the leakage or venting of methane from well infrastructure. In 2019, upstream activities released ~2.9 GtCO2e, or ~6% of the total annual greenhouse gases produced by human activity. As suppliers of energy to society, our industry has a vital role to play in taking action today to achieve a low-carbon future. TGT is at the forefront of this with our diagnostics-led sustainability framework. With this, our role is to help oil and gas producers deliver energy through the transition, but with significantly lower environmental impact. How can TGT help you reduce your carbon footprint? TGT is a different kind of company. Our unique technology and fresher thinking take us beyond the traditional restrictions of the wellbore, seeing more, seeing further. We create powerful diagnostics that help you to keep wells safe, clean and productive. Our diagnostics help operators and regulators achieve their NetZero targets by revealing inefficiencies in energy-intensive operations and locating sources of greenhouse gas. Equipped with the right information, our customers can take evasive action to improve energy efficiency, decarbonise operations and reduce environmental impact. We’re out of time. Not options.We’re out of time. Not options.Applications There are several areas where TGT can help you to reduce emissions and support your sustainability targets: Energy and resource efficiency Flaring Methane emissions Pollution Water management Carbon capture and storage Enabling cleaner energy

Energy and resource efficiency

Energy and resource efficiencyEnergy and resource efficiency Overview Infrastructure performance Intervention efficiency Improve injection performance Reduce water production Go to section OverviewInfrastructure performanceIntervention efficiencyImprove injection performance Reduce water production Home Search Results Producing hydrocarbons requires energy. Turbines and diesel generators account for 70% of upstream CO2 emissions. Our diagnostics can help you become more energy efficient and reduce your carbon overhead.Improve infrastructure performance Building and operating hydrocarbon extraction infrastructure represents a huge investment in energy, capital, time, materials and people resources. Maximising the return on that resource must be achieved, while protecting people and the planet. If a well or reservoir is not producing to its full potential during its life then the resource that built or operates it is not being fully leveraged and some is being wasted. Equally, if maintenance and workover resources are being utilised, they should operate efficiently and contribute to overall asset performance with the goal of keeping wells safe, clean and productive. All TGT diagnostic products are adept at revealing inefficiencies and guiding measures that enable existing infrastructure and resources to operate at maximum efficiency. For example, if a well is producing at high water cut, our Total Flow product will reveal the exact sources of water to enable targeted remediation. True Integrity products can be used proactively to identify casing weakness before the casing fails, helping to maintain asset performance and preventing more costly scenarios. Equally, because workover and rig resources are better targeted, time and energy is saved in getting the job done right first time. TOTAL FLOW CASE STUDYPRIMARY SEAL INTEGRITY CASE STUDY Drilling a single deepwater well can produce more than 20 ktCO2 Improve intervention efficiency Well delivery and intervention operations such as drilling, fracking, workovers, decommissioning [P&A] and diagnostic surveys require energy intensive surface equipment. Rigs, trucks, and pumps derive power from diesel engines or gas turbines that emit CO2 when the fuel is burned. A typical semi-submersible drilling rig emits roughly ~130 tCO2 per day and a Light Well Intervention vessel around 30 tCO2 per day. Improving efficiency and minimising the time to perform operations is a key factor in reducing energy consumption and emissions. All TGT diagnostic products deliver insights that enable all types of operations to be carefully planned and precisely targeted so they can be executed efficiently with precision. Also, by enabling ‘lighter’ or ‘rigless’ interventions, our diagnostics can be deployed with minimal carbon footprint before heavier equipment is mobilised. Lastly, because through-barrier diagnostics provide a more complete picture, we provide maximum information in the minimum amount of time. Time savings translate to both cost and carbon savings and our aim is make every hour count. MULTI TUBE INTEGRITY CASE STUDY A typical Jack-up rig emits 70 tCO2 per day. Improve injection performance Most oil reservoirs will inevitably require additional pressure support to maintain production and improve oil recovery. Water injection is used widely for this purpose and many oilfields are injected with tens to hundreds of thousands of barrels per day. Pumping water is energy intensive and the resulting CO2 emissions can range from 1-2 kgCO2 per barrel. In fact, water injection is responsible for ~40% of total CO2 emissions for a typical oilfield. Making matters worse, well completion and formation integrity issues can lead to water being diverted away from the target reservoir. This can result in abnormally high injection rates, reduced field production performance, and high water cut in producer wells. TGT’s True Flow products are being used globally by operators to ensure that all injected water is reaching the target and revealing where it is not. In many cases, these diagnostics lead to a significant reduction in water volumes and CO2 emissions, and increased field production. RESERVOIR FLOW CASE STUDYFIBRE FLOW CASE STUDY Pumping 10,000 barrels of water per day produces 5.4 ktCO2 annually Reduce water production High water cut is a persistent industry challenge responsible for unnecessarily high CO2 emissions and higher carbon per barrel. Excess water needs to be managed at surface, treated then reinjected or disposed of, and this requires energy. Also, excess water often means less oil, reduced recovery and longer production times, increasing emissions even further. And complicating the issue, produced water may be channeling from several elusive sources hidden behind the casing. In many cases, excess water cut can be minimised or cured. If the operator can identify the true source of water downhole, measures can be taken to shut-off the water and restore oil production to lower carbon and economic levels. TGT’s True Flow products are used widely for this purpose. Unlike conventional diagnostics that can only detect water entering the wellbore, TGT’s through-barrier diagnostics can reveal the true source behind casing, enabling effective remediation, improved recovery rates and reduced carbon emissions. MULTI-SEAL INTEGRITY CASE STUDYTOTAL FLOW CASE STUDY High water-cut leads to higher CO2 per barrel and lower oil production rates.

Enabling cleaner energy

Enabling cleaner energyEnabling cleaner energy Overview Secure gas storage Go to section OverviewSecure gas storage Home Search Results To reduce carbon emissions, society needs to switch from fossil fuel energy to alternatives. However, non-fossil sources only satisfy 17% of the world’s energy demands. As a transition fuel, gas offers a cleaner alternative to coal, provided it doesn’t leak from infrastructure.Secure gas storage To reduce greenhouse gas emissions, society needs to switch from fossil fuel energy to alternative forms. In 2020, only 17% of the world’s energy came from non-fossil sources, 31% came from oil, 25% from gas, and 27% from coal. At 56% of the energy mix, oil and gas are still essential. Whilst oil and coal use are in decline, gas use is trending up. Gas is the cleanest burning fossil fuel, but with the increase in use comes the risk of methane leaks in production and storage wells. Since methane is 85x more potent as a greenhouse gas than CO2, the integrity of producing and storage wells is essential in enabling cleaner energy solutions. Used proactively, TGT’s True Integrity diagnostics can be used routinely to validate seals in gas producing and storage wells, and assure methane containment. Burning 1kg methane produces twice the energy and half the CO2 than 1kg coal

Decarbonise with diagnostics

Decarbonise with diagnosticsDecarbonise with diagnostics Overview Decarbonise video Greenhouse gas emissions How can TGT help? Applications Go to section OverviewDecarbonise videoGreenhouse gas emissionsHow can TGT help?Applications Home Search Results Global warming, climate change, and hydrocarbons Today, global warming is an existential crisis facing our planet and all of its inhabitants. Climate science tells us that if global average temperatures rise more than 1.5°C above pre-industrial levels, the impact could become catastrophic and irreversible. In the oil and gas industry, we are all aware of the very real impact the climate crisis is having on society and the planet. Whilst we provide energy for the world to prosper, the way most of this energy is produced as well as consumed, is ultimately leading to climate change. Whilst we continue to develop clean energy solutions, the reality is that ~56% of the global energy mix continues to come from hydrocarbons, and it will take years, if not decades, before the balance shifts to cleaner sources. Global warming, climate change, with diagnostics Today, global warming is an existential crisis facing our planet and all of its inhabitants. Climate science tells us that if global average temperatures rise more than 1.5°C above pre-industrial levels, the impact could become catastrophic and irreversible. In the oil and gas industry, we are all aware of the very real impact the climate crisis is having on society and the planet. Whilst we provide energy for the world to prosper, the way most of this energy is produced as well as consumed, is ultimately leading to climate change. Whilst we continue to develop clean energy solutions, the reality is that ~56% of the global energy mix continues to come from hydrocarbons, and it will take years, if not decades, before the balance shifts to cleaner sources. Watch our video to find out moreGreenhouse gas emissions in GtCO2e Every barrel of oil or gas equivalent has a carbon overhead because of the energy consumed to produce it, the flaring of gas, and the leakage or venting of methane from well infrastructure. In 2019, upstream activities released ~2.9 GtCO2e, or ~6% of the total annual greenhouse gases produced by human activity. As suppliers of energy to society, our industry has a vital role to play in taking action today to achieve a low-carbon future. TGT is at the forefront of this with our diagnostics-led sustainability framework. With this, our role is to help oil and gas producers deliver energy through the transition, but with significantly lower environmental impact. Every barrel of oil or gas equivalent has a carbon overhead because of the energy consumed to produce it, the flaring of gas, and the leakage or venting of methane from well infrastructure. In 2019, upstream activities released ~2.9 GtCO2e, or ~6% of the total annual greenhouse gases produced by human activity. As suppliers of energy to society, our industry has a vital role to play in taking action today to achieve a low-carbon future. TGT is at the forefront of this with our diagnostics-led sustainability framework. With this, our role is to help oil and gas producers deliver energy through the transition, but with significantly lower environmental impact. How can TGT help you reduce your carbon footprint? TGT is a different kind of company. Our unique technology and fresher thinking take us beyond the traditional restrictions of the wellbore, seeing more, seeing further. We create powerful diagnostics that help you to keep wells safe, clean and productive. Our diagnostics help operators and regulators achieve their NetZero targets by revealing inefficiencies in energy-intensive operations and locating sources of greenhouse gas. Equipped with the right information, our customers can take evasive action to improve energy efficiency, decarbonise operations and reduce environmental impact. We’re out of time. Not options.We’re out of time. Not options.Applications There are several areas where TGT can help you to reduce emissions and support your sustainability targets: Energy and resource efficiency Flaring Methane emissions Pollution Water management Carbon capture and storage Enabling cleaner energy

Cascade3

The most powerful flow analysis platform ever created for horizontal well systems Made by experts for experts, Cascade3 builds on two decades of practical knowledge and experience applying science and mathematics to solving the most complex downhole flow scenarios. Incorporating the industry’s most advanced thermodynamic and hydrodynamic modelling codes, Cascade3 transforms temperature, pressure, and other well system data into continuous reservoir flow profiles. Crucially, the flow profiles reflect flow activity in and out of the reservoir, delivering the truest picture possible of reservoir behaviour and inflow/outflow downhole. The new Horizontal Flow diagnostics powered by Cascade3 overcomes many of the challenges faced by conventional production surveys, delivering a more reliable and complete assessment of flow dynamics in horizontal wells in a wider range of completion scenarios. Equipped with the right information, asset teams can take direct action to keep well and reservoir performance on track. Cascade3 brochure Modelling At the heart of Cascade3 is Torrent – a remarkable modelling and simulation engine that predicts the hydrodynamic and thermodynamic behaviour of fluids and their surroundings as they flow through the well-reservoir system.   Torrent features a unique 3D fine-grid modelling framework and can simultaneously solve three distinct flow geometries – radial, spherical, and linear in fractures – reflecting the three main types of flow that occur in a horizontal well system. Apart from providing a more realistic flow modelling environment, these features mean that Cascade3 delivers accurate continuous flow profiles in a wide variety of completion and reservoir settings, including fractured formations. FeaturesBenefits Production and Reservoir Engineers depend on downhole flow profiles to manage well and reservoir performance. Conventional wellbore production surveys can only sense certain flows entering the well completion and cannot measure inflow/outflow where it matters most – at the reservoir behind the completion. Also, even wellbore flow profiles can be compromised in open hole, and by viscous fluids, low flow rates and the complex flow regimes that occur in horizontal wells. Incorrect flow profiles can lead to missed opportunities and poor well and field management decisions. Horizontal Flow with Cascade3 solves many of the diagnostic challenges faced by Reservoir and Production Engineers, providing them with the flow insights they need to reduce operating costs and energy consumption, and increase ultimate recovery. Full benefits table found here. Cascade architectureProgrammes & methodsTools & measurementsProcessing & modelingAnalysis & interpretationProducts Platform partners Cascade3 works alongside three other technology platforms—Chorus, Indigo and Maxim, that together constitute the True Flow diagnostic system. Each platform has a specific role in providing Horizontal Flow insights. Whereas Cascade3 quantifies flow activity by modelling and simulating temperature and pressure changes in the well system, Chorus locates and characterises flow activity by sensing and imaging acoustic energy. For example, Chorus data can help the analyst distinguish between wellbore flow, reservoir or matrix flow and fracture flow, and provide a clear indication of active zones. And both temperature and acoustic data can help distinguish between liquids and gas.   Multisensory Indigo provides a host of wellbore measurements, including high-precision temperature that feeds into Cascade3, pressure, and a range of standard and unique production sensors, as well as real-time data transmission to the surface. Maxim is the digital workspace where analysts plan the diagnostic programme, integrate, and process the acquired data, perform the modelling and the in-depth analysis delivered in the final Horizontal Flow answer product. Resources Platform flyers(8) Hardware specifications(7) Case studies(36) Technical papers(128) Intellectual property(48) More(45) Product flyers(22) System flyers(2) White papers(0) Product animations(21) Resources

Safe and Sound P&A. Decommissioning wells using acoustics

Here are alternative solutions to improve P&A operations by reducing cost and increasing the reliability of E&P operations Article featured in Harts E&P Magazine Today, more and more wells are reaching the end of their economic life and need to be decommissioned—a process often referred to as Plug and Abandonment (P&A). Many factors need to be considered when designing an effective P&A operation, especially those that relate to barrier integrity, such as cement bond quality, the presence of behind casing flow, and potential inflow zones. Oil and gas producers are obligated to perform P&A operations in accordance with regulations and guidance typically developed in collaboration with government bodies to ensure that decommissioned wells and safe and secure. The main objective of P&A is to restore previously penetrated natural barriers by securing potential barrier failures within the well system. These failures could be related to steel or cement barrier degradation during the operational phase of the well. Steps are taken to verify the sealing capacity of so-called external well barrier elements, including cement bonding, shale or formation creep, and baryte sediments. For offshore wells, re-entry of decommissioned wellbores becomes virtually impossible after a new lateral has already been drilled or when topsides have already been removed. Therefore, it is critical that the well is robustly and permanently sealed. The resources required and cost of planning and performing a P&A operation are mainly driven by the complexity of the P&A, including whether it can be done riglessly or with a drilling rig. The operator has to strike a balance between meeting the required regulatory needs, deploying the required diagnostics tests, and optimising the time spent to prepare and execute the process. Fig.1: Example of the cost estimation of the onshore geothermal well P&A. Click image to view full report. This P&A cost is not an investment into future profit. It is an investment in protecting the environment and eliminating future hazards. In order to address all concerns, operators are seeking alternative solutions to improve the efficiency and effectiveness of P&A operations by reducing cost and at the same time increasing the reliability of operations. Today, ‘P&A optimization’ is developing in two main areas: A transition towards ‘rigless’ mode, where P&A operations are performed using slickline, wireline or coil-tubing before the rig moves to the well. Rigless operations may include the abandonment of the reservoir, verification of the well barriers and gathering the input parameters for P&A sequence improvement. The key advantage here is to verify the existing well barriers when the tubing is still in the well. There are recent developments in tubing cement logging (spectral acoustics and through tubing ultrasound), enabling the evaluation of cement bond and seal with certain thresholds to determine barrier isolation. Utilization of alternative or natural barriers instead of conventional cement barriers. This allows P&A engineers to consider shale and formation creep, salt dome, squeezing bismuth and polymers to improve the sealing of the external well barriers and take the reliability of the barriers to the next level. The main advantage that operators see today is that shale, for example, may work as the best downhole barrier, because it does not degrade with time, has close to zero permeability, and may even seal potential future leaks or failures. In fact, simple calculations show that 30 m average cement barrier (as per NORSOK and U.K. P&A guideline) with permeability of 20 micro darcy will start to leak at a rate of 0.25 m3 gas a year if 1,000 psi pressure is applied. A similar leak rate for typical shale creeps permeability will only be observed in the presence of 2-5 m of well-bonded shale. The same 30 meters of shale will be almost impermeable (link to the presentation). Fig.2: Graph showing the optimization of the P&A process. Operators typically plan P&A processes years in advance and develop the strategies individually for each well, taking into account the construction of the well, lithology and the technologies available on the market today. Above all, the strategy should meet the requirements of the regulatory bodies of the country in which the operator abandons the wells, as well as the operators own policies. The example below shows the experience of a North Sea operator in using ‘P&A optimization.’ To improve the P&A process and demonstrate the ability of natural barriers to withstand reservoir pressure, the operator performs a test of the shale barriers for future abandonment. For a particular field on the Norwegian Continental Shelf, characterization of the overburden formations indicated that a simplified permanent P&A strategy is possible based on a concept with annular sealing from ‘creeping’ Green Clay and a buffering capacity in the underlying Balder formation. Leak scenario simulations with a fracture growth simulator concluded that such a permanent P&A strategy is robust against deep gas migrating, given that a sufficient stress contrast is present between the sealing Green Clay and the Balder. Estimates of the stress profile in the overburden derived from sonic logs indicated such a favorable stress profile is present. However, this stress profile had to be confirmed by dedicated stress tests. Consequently, ‘Extended Leak Off Tests’ (XLOT) were planned and performed during the P&A operations in both the Balder and Green Clay. The XLOT in the Balder formation was performed through perforations in the intermediate casing. However, as the Balder interval consisted of varying degrees of poorly bonded cement, this introduced a risk of uncertainty with regards to depth control—where the fracture(s) propagate and if there is communication to above or below the Balder formation. To mitigate this risk, the operator utilized TGT’s True Integrity system with Chorus acoustic technology, combined with downhole temperature and pressure sensors positioned close to the perforation depth. Chorus and its ‘Acoustic Power Spectrum’ was used to establish the injection/fracture point in the Balder during the XLOT and confirm the integrity of cemented casings above and below the Balder. Fig.3(a): Advanced Extended Leak Off Test. Chorus tracks and classifies the flow behind 13 3/8” through tubing. Deployed riglessly and through tubing, the Chorus Acoustic Spectrum enabled the induced flow classification (no flow, channeling in cement, and fracture flow) in the Balder formation and revealed the fracture initiation points behind the casing. It also confirmed there are no issues with cement seal integrity with accuracy of 15 psi/day pressure failure or 10 ml/min of leak rate. The XLOT test conducted by the operator showed the main test output list can be extended in cases where Chorus acoustic monitoring is implemented. This case proved that the integration of the downhole data acquisition can be performed with no interference in the traditional XLOT program. Fig.3(b): Advanced Extended Leak Off Test. Chorus tracks and classifies the flow behind 13 3/8” through tubing. The Chorus Acoustic Power Spectrum visualizes active induced fractures and cement seal integrity behind the casing. The exact fracture depth can be determined and capacity analysis can be performed by monitoring the decay of the acoustic signal over time during the flowing-back stage. Cement sealing can be verified by interpretation of the acoustic signature recorded across the cement barrier. The above-listed unique datasets can be used today by rock mechanics, well integrity, and well abandonment engineers. With the right combination of technologies, good planning and execution, the operation was successful and results were confirmed, in addition to validating the sealing Green Clay intervals, a stress contrast of 11 points, and proving this new permanent P&A concept (details in SPE). This enabled the consideration of the shale barriers such as Balder for permanent P&A. Decommissioning a well securely and permanently requires both an accurate P&A program and the use of alternative barriers to ensure long-term, sustainable integrity. It is essential to use proven verification techniques to inform the P&A program and validate the seal integrity of critical barriers.

Harts E&P’s 40 Under Forty Award

Artem Khasanov, TGT’s QHSE & Testing Laboratory Team Leader is an honoree in Hart Energy’s E&P 2021 “40 Under Forty” recognition program Article featured in Harts E&P Magazine From an early age, Artem Khasanov was interested in learning how the world works, so he started studying physics and technology. Khasanov studied physics at Kazan Federal University, where he was first engaged in semiconductors research and then, in collaboration with the Kazan Institute of Chemical Technology, was engaged in research of silicone rubbers. “I am 107% sure (this is an accurately measured value) that the main quality of a researcher and developer is the ability to be a good observer,” he said. “Many secrets of the world are revealed if you are thoughtful enough.” In 2013 Khasanov started working with TGT as a laboratory assistant, and he became a research engineer a year later. He added, “Once I realized that there is an industry where people who are passionate about technology and research are rewarded well—the oil industry—there was no stopping me!” In 2019 Khasanov became the head of the testing laboratory. He devoted a significant part of his work to the study and application of ‘acoustics’ in oil and gas wells, as a means to locate and characterize fluid flow. Acoustic technology is a key ingredient in TGT’s diagnostic systems—used by its customers globally to keep wells safe, clean and productive. Career goals “When I started my career, I met so many competent and talented people who strive to innovate and develop new technologies. My first task was to catch up with my peers in terms of competence and knowledge. Now I am studying international quality standards to ensure that our diagnostic systems and products continue to set and exceed industry standards.” Memorable technology projects “I have led several projects that have helped the company advance diagnostic methods and technology. For example, I designed and manufactured laboratory models for researching and developing sophisticated multisensor acoustic devices. I also developed systems to study the acoustic signature of fluids flowing through rocks and barrier leaks, as well as apparatus to study the acoustics of sand production; and automatic testing devices for our diagnostic systems. All of these projects ultimately help our customers make better-informed decisions.” Motivation from within “After a certain age, a person needs to stop looking for a mentor and become one. All the necessary information is available; you should just lend a hand. You don’t need a mentor to make history. All you need is purpose, motivation, and health. And believe it or not, your best advisor is – yourself! One of my guiding principles is, ‘If you are in doubt about what to do, just do what is right.’” Formative experience “The most important thing in any business is to control emotions and direct personal energy to an ultimate goal. Therefore, among the many educational programs I’ve undertaken, one of the most useful was all about emotional intelligence.” Sustainability & decarbonization “Whilst renewable energy sources are gradually increasing, more than 50% of the world’s energy supply still comes from hydrocarbon resources – so the extraction of oil and gas is a necessity. Our mission at TGT is to help the industry keep oil and gas wells safe, clean and productive. We are helping our customers to decarbonize and reduce harmful emissions. I’m motivated by the fact that the diagnostic systems and products that we create make it possible to use the planet’s resources more sustainably.” Industry’s future “I believe that the ultimate goal of any industry is to make our lives healthier, happier and more sustainable. Collectively, we need to find the right balance between maintaining human existence and protecting the planet and other species that live beside us. We need to keep in mind the countless scientists, engineers, analysts and other oilfield workers who dedicate their lives to advancing this vital industry. Digitalization and automation will be important enablers of our future, together with the use of predictive diagnostics to improve the safety and integrity of well systems. “One day, after a couple of hundred years, our great-grandchildren, roasting marshmallows by the fire on Mars, will remember us with gratitude.” Artem Khasanov, TGT’s QHSE & Testing Laboratory Team Leader

Harts E&P Magazine – Tendeka and TGT have created “Sandbar” to mitigate the costly consequences of sand control failure in wells

Collaboration combats sand control failures Article featured in Harts E&P Magazine In mature basins, sand issues can account for up to 10% of all shut-in wells either due to failure of the existing downhole sand control or onset of sand production due to pressure depletion and/or water production. There are many reasons for sand or fine material entering and accumulating in the wellbore, and depending on the level of severity, the consequences need not be detrimental. However, the accumulation of sand production downhole or in surface equipment can lead to production being killed, wells shut-in, or collapse of the formation. As an inherent problem in the oil and gas industry, the first indication of sand issues downhole will often be as a result of detrimental effects that can occur at surface, such as fill in separators or erosional damage to pipe work. As existing solutions have been extremely limited due to their high cost and/or poor performance, together, independent global completions service company Tendeka and diagnostic specialists TGT have created Sandbar to mitigate the costly consequences of sand control failure in wells. Downhole monitoring and remediation The conventional process of thru-tubing sand control can be costly and time consuming. In many cases there is a requirement to remove sand from the wellbore prior to installing the chosen sand control solution. Once installed many traditional remediation techniques still allow the wellbore to refill with formation sand reducing productivity and increasing susceptibility to erosional failure. Therefore, the major challenge is to regain sand control in existing completions and prevent sand from filling the wellbore, without the requirement to perform a workover or complex thru-tubing gravel packs. Proper diagnosis is the critical first step to any kind of well remediation planning and execution. But determining the precise location and extent of sand ingress downhole has challenged the industry for decades, as previous attempts were unable to reliably distinguish between sand and fluid flow. The challenge of locating and effectively mitigating sand production has now been addressed by combining the features of two products, one to accurately identify the locations of sand ingress within the wellbore, and the other to quickly repair the damage. The conventional process of thru-tubing sand control can be costly and time consuming. In many cases there is a requirement to remove sand from the wellbore prior to installing the chosen sand control solution. Once installed many traditional remediation techniques still allow the wellbore to refill with formation sand reducing productivity and increasing susceptibility to erosional failure. Therefore, the major challenge is to regain sand control in existing completions and prevent sand from filling the wellbore, without the requirement to perform a workover or complex thru-tubing gravel packs. Proper diagnosis is the critical first step to any kind of well remediation planning and execution. But determining the precise location and extent of sand ingress downhole has challenged the industry for decades, as previous attempts were unable to reliably distinguish between sand and fluid flow. The challenge of locating and effectively mitigating sand production has now been addressed by combining the features of two products, one to accurately identify the locations of sand ingress within the wellbore, and the other to quickly repair the damage. Accurately eliminating sand issues Managing and curtailing sand production issues is essential to maintain asset integrity and extend the life of the asset. Tendeka and TGT have joined forces to create the more effective, intervention-based solution, ‘Find Fix Confirm’ sand remediation service, which is believed to be the first specialized, integrated approach to fully understand and fix sand production issues. First, the ‘Find’ element of the solution, whereby TGT’s ‘Sand Flow’ diagnostics precisely locates sand entry to the wellbore and provides a qualitative sand count, clearly identifying problem zones, even in turbulent flow conditions (Figure 1). Figure 1: TGT’s Anechoic Chamber completely absorbs reflections of sound and electromagnetic waves, enhancing the company’s acoustic diagnostic capabilities Although commonly used to diagnose a known sand production issue, Sand Flow is also used proactively to ensure downhole sand control measures are working correctly. This can include targeting unconsolidated formation that requires regular intervention, sand screen failure, and surface equipment failure. Sand Flow diagnostics are delivered using TGT’s ‘True Flow’ system and ‘Chorus’ acoustic sensing platform. Fluids travelling through the well system produce a rich spectrum of acoustic energy, and Chorus captures and decodes the acoustic signature generated by sand particles entering the wellbore. Deployed in hole on wireline, Chorus reveals sand ingress locations and sand count by analysing the acoustic power spectrum of acquired data, and discriminating between sand flow and fluid flow. By flowing from the reservoir whilst the tool is in the well, the acoustic signature of any sand within the production stream can be characterized such that the sand entry points and sand rate can be identified. Chorus leverages high-fidelity recording across a wide dynamic range and proprietary sand-recognition analysis to deliver robust sand detection in a broad range of sand flow scenarios. To ‘Fix’ or regain sand control in existing completions and prevent sand from filling the wellbore, Tendeka’s one-trip, thru-tubing sand control system ‘Filtrex’, is deployed via coiled tubing into the well and positioned across the target area to quickly repair the breach or damage (Figure 2). Figure 2: Sand clean out and screen installation by Filtrex is performed across three key stages As a retrievable thru-tubing system, the flexible, open cell matrix polymer filter can be easily installed by conventional means in a live well, this includes thru-tubing, and through tight nipple restrictions. When self-centralized, it can expand in deviations up to 90˚ and is understood to be the only product of its kind that can be run through larger casing/liner configurations, for example, a 3.688-in. nipple and set in a 7-in. liner. It can be deployed in-hole compressed within the running tool and compression sleeve. This offers full compliance to the damaged section once set. By dropping a ball from surface, a simple two-stage application of pressure firstly sets the anchor, and secondly releases the compression sleeve. Upon removal of the sleeve, the matrix polymer expands to contact the wellbore and the deployment string can be retrieved from the well. Filling the annular gap with the open cell matrix polymer prevents further ingress of formation solids into the wellbore whilst still allowing passage of liquids or gases. The multilayer system ensures full expansion in the damaged screen section or casing and effective flow divergence regaining sand control in existing completions (Figure 3). Figure 3: Filtrex expanding out of compression sleeve The first of its kind, the device can perform sand clean out and chemical treatments during live well deployment, thereby preventing multiple intervention trips. When deployed on coiled tubing the installation of the system has the potential to significantly improve the financial feasibility of restoring production to failed wells. As it negates the need for a workover or complex thru-tubing gravel packs, the remedial system can also cut intervention timings and associated run changes by at least half. The length can be modified to suit the application and lubricator length restriction. If longer lengths are required these can be stacked on top the previous screen section. The system design allows the combination of many distinct layers with a range of cell sizes. This ensures the design has the flexibility to size the screening for each application to ensure appropriate retention of sand in reservoirs up to 110°C (230°F). Finally and crucially, the service can ‘Confirm’ the effectiveness of the solution with the redeployment of TGT’s Sand Flow diagnostics through the internal diameter of the Filtrex system to confirm that no sand is entering at that depth. This enables better use of resources and more reliable sand control outcomes. Innovation through partnership As a single approach, existing remedial methodologies to address sand management, such as running an insert sand screen, applying consolidation treatment or performing a remedial gravel pack, are disjointed, lack insight on the precise location of the problem, and often fail to fully eliminate the problem. Likewise, their use can vary in complexity, cost, risk, longevity and effectiveness. Associated weaknesses can often result in reduced production or in extreme cases, loss of surface containment due to erosion. Bringing together two technologies in one service offering will ensure fast, accurate and tailored remediation to a variety of sand control issues at a fraction of the time, cost and risk of conventional solutions to this age-old problem. Being compatible with thru-tubing operations, including live well deployment and single trip sand clean out, provides greater flexibility and assurance. Ultimately, it will empower operators to better understand the true sources of sand production and its behaviour and ensure reservoir management decisions are precisely targeted for improved integrity and enhanced asset life.

Product flyers

Sandbar – Find, Fix, Confirm

Sandbar is a joint solution with Tendeka that delivers precise, reliable and effective downhole sand remediation.Background Sand production from oil and gas reservoirs is a serious issue. It can decimate productivity and erode the integrity of well completions and surface assets. Often, the first indication of sanding issues downhole are the detrimental effects that can occur at surface, such as fill in separators or erosional damage to pipework. Thru-tubing remediation typically involves an interval approach for a problem which may be localised. Historically, this is because there is a duality of issues in the ability to accurately identify the location of sand ingress and to target a localised fix. Surface monitoring can detect when sand is being produced, but locating the source and dynamics of sand inflow downhole is essential to protecting integrity and maintaining production. Tendeka and TGT’s combined “Sandbar” sand remediation solution addresses all of these issues to offer a more precise, reliable and effective intervention-based solution. It follows a simple process flow of "Find, Fix, Confirm". Technology in Action TGT’s Sand Flow product precisely locates sand entry to the wellbore and provides a quantitative sand count, whilst Tendeka’s Filtrex remedial sand control system is precisely targeted to repair the damage. Crucially, Sand Flow is then redeployed to confirm the repair. Find Sand Flow diagnostics are delivered using TGT’s “True Flow” system and the “Chorus” acoustic sensing platform. Chorus is deployed on wireline, capturing and decoding the acoustic signature generated by sand particles entering the wellbore and impacting the tool. It analyses the acoustic time-domain data to discriminate between sand flow and fluid flow, thus locating the sand entry points and quantifying the sand rate. Fix Tendeka’s Filtrex is deployed into the well on coiled tubing and positioned across the target area. Dropping a ball in to the string allows pressure to be applied in two stages, firstly to set the anchor, and secondly to release the compressions sleeve. Upon removal of the compression sleeve, the matrix polymer expands to contact the wellbore and the deployment string can be retrieved from the well. Confirm The same diagnostics are run in the “Find” scenario, but this time deployed through the internal diameter of the Filtrex system to confirm that no sand is entering at that depth. Value to your business One-stop diagnose, fix, verify solution Restore integrity and productivity Reduce intervention time Improve resource efficiency, lowering emissions Reliable and cost-effective sand control Sandbar brochureSandbar Tech brief Sandbar - joint sand remediation solution with Tendeka Tendeka's Filtrex solution

Pulse

Pioneering electromagnetics delivering highly accurate tube integrity diagnostics The miles of metal tubes that form the backbone of your well system are fundamental to its integrity. Tracking the condition and wall thickness of all tubes is essential to maintain a secure well. The ‘electromagnetic signature’ of each tube contains information about the wall thickness, but extracting this accurately pushes the boundaries of electromagnetics, 3D modeling, and wellbore measurements to the furthest limits. That’s exactly what we’ve managed to achieve with Pulse. Pulse powers our True Integrity Tube products to accurately assess up to four concentric tubes from inside the wellbore. And unlike conventional systems, it works in all completion types, including dual string and corrosion resistant alloys. Pulse architectureProgrammes & methodsPulse is deployed using industry standard diagnostic programmes.Pulse is deployed using industry standard diagnostic programmes. Tools & measurementsUltra-fast sensor technology with rapid relaxation work with patented time domain measurements to deliver supreme accuracy in all completion materials, including specialised alloys with high chrome and/or nickle content. Multi-sensor tool design and proprietary ultra-fast coils optimise energy transfer with each tube, to deliver industry-leading accuracy in multi tube completions. Sensors designed and built in-house, incorporating tuned geometry and ‘fast coil cores’.Ultra-fast sensor technology with rapid relaxation work with patented time domain measurements to deliver supreme accuracy in all completion materials, including specialised alloys with high chrome and/or nickle content. Multi-sensor tool design and proprietary ultra-fast coils optimise energy transfer with each tube, to deliver industry-leading accuracy in multi tube completions. Sensors designed and built in-house, incorporating tuned geometry and ‘fast coil cores’. Processing & modelingOur model solves Maxwell equations which help transform raw data into accurate wall thickness measurements in all well geometries, including dual string completions, so you know your well’s condition from top to bottom.Our model solves Maxwell equations which help transform raw data into accurate wall thickness measurements in all well geometries, including dual string completions, so you know your well’s condition from top to bottom. Analysis & interpretationAnalysts leverage their deep experience in performing tube integrity analysis in thousands of wells globally. Maxim, our digital workspace, provides analysts with a host of Pulse Apps and versatile visual displays to facilitate detailed analysis and confident interpretation.Analysts leverage their deep experience in performing tube integrity analysis in thousands of wells globally. Maxim, our digital workspace, provides analysts with a host of Pulse Apps and versatile visual displays to facilitate detailed analysis and confident interpretation. ProductsOur products offer critical well diagnostics to address the full spectrum of well system flow and integrity challenges.Our products offer critical well diagnostics to address the full spectrum of well system flow and integrity challenges. Our approach We recognise that delivering accurate diagnostics requires not only the highest fidelity measurements, but also a system-based approach. It is important to have the best sensors and measurements, but it also important to use them in the right way and then to filter, process and model the data into tangible answers. We pursue a diagnostic system approach where multiple platforms come together, bringing their own unique diagnostic capability to be used in the framework of the proven workflow. Pulse is our electromagnetic platform, providing accurate barrier-by-barrier assessment of up to four concentric tubulars from a single through-tubing deployment. Pulse platform is part of our True Integrity System and is used to evaluate the metal condition of tubulars throughout the well system. Pulse supports the diagnostic answers for the True Integrity Tube products Pedigree 10 years of pioneering scientific research, ingenuity and direct field experience in applying electromagnetic diagnostics to thousands of well systems globally. Five international patents for electromagnetic technology and methods. Extensive ‘multi-barrier’ research, testing and calibration facilities enable continuous advancement of electromagnetic diagnostics. Experts in high-performance, fast switching electronic circuit design and 3D numerical modeling. Designed and built entirely in-house at our Technology Centre. Pulse family Our Tube Integrity products rely on the Pulse, Indigo and Maxim platforms to deliver an accurate assessment of tube condition. Depending on the product and its application, we utlise a specific combination of Pulse sensors to achieve the desired diagnostic objective. Each sensor is designed to energise certain tubulars or ‘barriers’ and is arranged in the Pulse tool string used to survey the well. We deploy a range of Pulse variants according to the number of barriers to be surveyed. Pulse1 is optimised to deliver ‘true wall thickness’ measurements of production tubing in eight sectors, with complete all-around sensing of tube wall condition. And for simultaneous assessment of multiple barriers, Pulse2, Pulse3 and Pulse4 are utilised for two, three and up to four barriers respectively. The multi barrier variants can be combined with Pulse1 for a more detailed assessment of the well completion. Resources Platform flyers(8) Hardware specifications(7) Case studies(36) Technical papers(128) Product flyers(22) More(50) System flyers(2) Intellectual property(48) White papers(0) ResourcesMediaWe strive for continuous advancement of electromagnetic diagnostics.Extensive ‘multi-barrier’ research, testing and calibration facilities.