Dubai, UAE - 28 June 2021 TGT Diagnostics, leaders in through-barrier diagnostics for the oilfield, today announced the appointment of Andre Sayeh as Chief Financial Officer. In this role, he will be responsible for managing all aspects of TGT’s finance, compliance and legal functions.   Andre will focus on maintaining the high standard of financial rigor for which TGT is well known, as well as continuously improving business processes to support our expanding geographical footprint.   TGT CEO, Mohamed Hegazi commented, “Andre brings extensive knowledge of the finance function and an impressive depth of experience spanning strategic global roles in one of the industry’s most respected brands. I’m delighted that Andre has joined our executive team at a time when there are so many positive dynamics around us, including a fast-paced digital transformation, a post-pandemic recovery, and a growing ESG momentum.”   Andre joins TGT Diagnostics with more than 30-years’ experience with the oilfield services firm Schlumberger. His prior roles include Global IT Vendor Management, Business Systems Special Projects and Global ERP Portfolio Manager, as well as numerous Financial Controller and Tax Manager roles for multiple businesses.   Andre holds a Bachelor’s Degree in Banking and Corporate Finance, and a minor degree in Marketing from Kuwait University. In addition to driving many financial achievements, Andre has led several global contract negotiations and ‘ERP Business System’ consolidation projects relating to company acquisitions. Andre also led the design and implementation of a new ‘ERP Business Demand Portal’ for the finance function, the concept and architecture of which was adopted by other corporate functions across the organisation.   “TGT is the category leader in oilfield diagnostics with an impressive reputation in the industry; I look forward to helping the company achieve its full growth potential and utilising my skills and experience to bring process automation to the next level.” Commented Andre. “I feel privileged to be part of TGT team, as it brings unique diagnostic products that sets it apart from other brands, and I see a tremendous opportunity for the company to play a crucial role in helping the oil and gas sector deliver a sustainable future.”

Kazan, Russia, 2018: TGT Oilfield Services, the market leader in through-barrier diagnostic systems, celebrated 20-years of Research and Development and technological advancements.   Mohamed Hegazi, Chief Executive Officer, said: “We are delighted to have reached this milestone, especially in an increasingly competitive market place and at a challenging time in our industry. We enjoyed our celebration with valued employees, partners, and customers from around the world. This achievement is a testament to the uniqueness and strength of TGT ‘s technologies, Geoscience expertise and best in class service delivery”.   “The past 20-years have been an incredibly exciting time for us. We have continuously outpaced the market growth, expanded our geographical footprint and continue to be actively engaged in industry forums and publications. TGT uniquely designs, develops, manufactures and patents its own hardware and software”.   TGT has grown from a small office with a handful of employees, to a company with 12 offices globally, operating in more than 20 countries for more than 40 customers. Mohamed Hegazi, CEO, TGTBringing global colleagues together to celebrateArthur Aslanyan, Founder, TGTTraditional Russian dance To celebrate, TGT invited employees, customers, and business partners to an evening which relived the company’s scientific breakthroughs using acoustic, thermal and electromagnetic energy to reveal unique answers within and beyond the well bore.   Dr. Arthur Aslanyan, TGT’s Co-Founder commented, “It gave me great pride to attend the event and celebrate the company's 20th anniversary. We have come a long way since we first started the business. We are very excited about our future as the company continues to thrive”.   The event was attended by Saad Bargach, TGT Chairman and LimeRock Partners -private equity investors.   Hegazi continued, “Looking to our future, TGT is releasing several lines of new technologies and applications in coming months to further cement our position as pioneers of Through-Barrier Diagnostics. Our patent technology developments coupled with our unrivalled Geoscience organisation and global footprint, provide unique and reliable diagnostic services to our customers. This has been key in maintaining our fast growth trend and industry reputation. I am confident this foundation along with our excellent teams, will continue to fuel our growth for many years to come.

TGT Oilfield Services, the leader in through-barrier diagnostic systems for the oilfield, has announced the appointment of Ken Feather as its chief marketing officer.   Based in TGT’s global headquarters in Dubai, marketing and brand expert Feather will lead the company’s strategic initiatives for new products and brand development while reinforcing the company’s position as a leader in well and reservoir diagnostics. He will report directly to TGT’s chief executive officer, Mohamed Hegazi.   “I am really excited about Ken joining our management team,” said Hegazi. “He brings 30 years of extensive oilfield experience in sectors that align perfectly with our product portfolio. His track-record in launching oilfield technology and geoscience products, coupled with a deep knowledge of our market will bring valuable strategic and industry insights to our team.   “Ken has grown market share and brand recognition at some of the most notable oilfield technology companies, including Schlumberger and Archer, and he possesses the ideal mix of experience and expertise to help propel our business forward. His proven expertise in market strategy, brand positioning and communications will be pivotal to us as we continue to innovate new services, expand our global footprint and evolve our brand.”   Commenting on his appointment, Feather said, “TGT is respected as a pioneer in well and reservoir diagnostic systems and has built an impressive array of powerful brand ingredients. The company has its own research, engineering and manufacturing facility, and some of the world’s leading scientists and specialists in using heat, acoustic and electromagnetic energy to assess well and reservoir dynamics. “The company’s products and technology are highly-valued by its customers and there are more innovations on the horizon, reflecting the company’s drive to solve industry challenges and attract many new customers. This combination of factors is a ‘marketers’ dream, so I’m thrilled to be joining the TGT team at such an exciting time.”   Prior to TGT, Ken headed up his own company, Spinnaker Marketing, helping ambitious technology ventures in the energy sector become category leaders. Previous positions included vice president of marketing with well integrity and intervention technology specialist Archer where he launched several disruptive technology brands and an award-winning corporate rebrand. At Schlumberger, Ken progressed from field engineer and geoscientist to several highly regarded marketing roles across a variety of business units, earning his reputation as a marketing and sales specialist in the oil industry’s largest technology-led service company.   Born in Liverpool, UK, Ken is a chartered engineer and a fellow of the UK’s Chartered Institute of Marketing. He graduated from the University of Salford, UK, with a first class honours degree in Electrical and Electronic Engineering.   TGT operates globally in almost 30 countries, including in Europe, North America, Africa, Middle East, and Asia Pacific.

Improved asset performance for operators made possible by new approach to well diagnostics. TGT, the category leader in through-barrier diagnostics for the oilfield services market today unveiled one of the most radical business transformations in its sector. Motivated by a singular purpose – to reveal a greater truth – the company turns the industry’s way of doing business on its head; shifting the commercial approach from ‘logging tools’ to ‘Flow’ and ‘Integrity’ application-led ‘Products’.   “We’ve been pioneering advances in well diagnostics for 20-years and built an extensive portfolio of products, technology and customers,” said Mohamed Hegazi, TGT’s chief executive officer. “Our new offering will transform how our customers manage their wells, enable much better decision-making and boost asset performance”.   TGT has structured its new product-led offering in two domains—True Flow and True Integrity, each being a practical and symbolic extension of its ‘greater truth’ brand promise, and representative of what customers demand from their well systems.   “All well systems are built to connect the right fluids to the right places,” continued Mohamed. “Flow and integrity are intimately linked and essential for safe and productive operations.   That’s why we’ve organised our business in to these two domains. This business approach means our products and diagnostic systems are relevant to all wells throughout their lifecycle.”   “Tools are important but well systems are complex so accurate diagnostics require a more powerful approach. We have perfected ‘diagnostic systems’ that combine remarkable tools with the right methods, data processing and expert analysis to deliver accurate answers.” said Ken Feather, TGT’s chief marketing officer. “Operators need answers they can trust, so we developed a complete range for every eventuality.” continued Ken.   TGT’s new diagnostic systems use five proprietary technology platforms: Chorus, Cascade, Pulse, Indigo and Maxim, in various combinations to make the products.   “This exciting change marks a strategic pivot in our future direction as an oilfield service company,” added Ken. “The industry needs a fresh approach, and our new offering supported by a totally new and distinctive brand identity provides an incredible potential to grow.”   With its transformation efforts successfully implemented, TGT is now focused on championing the new through-barrier diagnostics category to help operators manage safe, productive and profitable wells. Among other developments, TGT expects to launch further new products and system advances throughout 2019. New product-led offering centres on two domains: Flow and Integrity Making their transformed debut are TGT’s five diagnostic platforms: Chorus, Cascade, Pulse, Indigo and Maxim About the new TGT brand identity The striking new brand identity, developed in collaboration with Handsome Brands, reflects all aspects of TGT’s new brand platform. It has been engineered to be distinctive and memorable and provide an important signposting function to help customers navigate through the offering.   The new portfolio of products and diagnostic systems is structured in two primary domains – True Flow and True Integrity, each representing the two most important performance factors for all well systems. Circles and squares have been used together with distinct colour palettes to create unique identifiable dynamic patterns that represent Flow and Integrity. Building on this, priority colours from each palette are used to signify the three main tiers of the brand system, namely, Corporate, Products, and Systems.   At corporate level, all the colours and patterns come together as one.   TGT’s brandmark has been simplified and strengthened in line with the clean and simplified approach of the new brand.

TGT Oilfield Services, the market leader in through-barrier diagnostic systems for the oilfield is pleased to announce that it has successfully completed the global auditing requirements for several essential quality, environmental and health & safety standards, namely ISO 9001:2015, ISO 14001:2015 and OHSAS 18001:2007. The certifications, which were awarded following a full-scale audit by IMQ, a European leader in conformity assessments for the electrical, electronic, gas and energy industries, demonstrates TGT’s commitment to the highest standards in quality management, environmental management and occupational health and safety management systems.   Commenting on the certification, Mohamed Hegazi, TGT’s chief executive said, “TGT’s commitment to quality, the environment and safety is integral to everything we do. Throughout our global business units, technology centre, interpretation centres and manufacturing facility, our staff take enormous pride in their work, and these ISO and OHSAS certifications will give our customers even more confidence that they are dealing with a company that rigorously adheres to the highest standards.   ISO 9001:2015 specifies requirements for a quality management system where an organisation needs to “demonstrate its ability to consistently provide products and services that meet customer and applicable statutory and regulatory requirements” and “aims to enhance customer satisfaction through the effective application of the system.” ISO 14001:2015 specifies the requirements for an environmental management system that an organisation can use to enhance its environmental performance, and OHSAS (Occupational Health and Safety Assessment Series)18001: 2007 is an internationally applied standard for occupational health and safety management systems. Quality assuranceHSSE management

Total well system integrity and ‘the containment and prevention of the escape of fluids’ (ISO TS 16530-2) remains one of the biggest challenges Middle East operators face today. The Middle East has been the world’s most prolific oil-producing region for decades with one of the largest populations of ‘hard-working’ aging wells – many of which operate continuously in extreme environmental conditions. More than 70% of the ~800 Middle East platforms and associated well-stock are more than 25 years old.   Not surprisingly, Middle East operators are facing a constant challenge to manage corrosion and sustained annulus pressure [SAP] in their well systems, and are always on the lookout for new innovations to help. This article will provide examples of two such innovations – corrosion surveillance in chrome-based tubulars, and addressing SAP. To celebrate, TGT invited employees, customers, and business partners to an evening which relived the company’s scientific breakthroughs using acoustic, thermal and electromagnetic energy to reveal unique answers within and beyond the well bore.   Dr. Arthur Aslanyan, TGT’s Co-Founder commented, “It gave me great pride to attend the event and celebrate the company's 20th anniversary. We have come a long way since we first started the business. We are very excited about our future as the company continues to thrive”.   The event was attended by Saad Bargach, TGT Chairman and LimeRock Partners -private equity investors.   Hegazi continued, “Looking to our future, TGT is releasing several lines of new technologies and applications in coming months to further cement our position as pioneers of Through-Barrier Diagnostics. Our patent technology developments coupled with our unrivalled Geoscience organisation and global footprint, provide unique and reliable diagnostic services to our customers. This has been key in maintaining our fast growth trend and industry reputation. I am confident this foundation along with our excellent teams, will continue to fuel our growth for many years to come. Overcoming chrome As Middle East well conditions become more corrosive, so operators have looked to more corrosion resistant materials in the completion process, leading to a rise in chrome and nickel content in steel tubulars. However, one unintended side effect is the decrease in the effectiveness of ordinary electromagnetic [EM] well and pipe inspection systems and the tracking of corrosion in multiple barriers.   The increase in chrome and decrease in ferrous content causes EM signals to decay too quickly for such systems to be truly effective in monitoring corrosion and evaluating pipe thickness or metal loss in casing strings. So while corrosion resistance may have increased, there is now a potential information vacuum.   TGT, the market leader in through-barrier diagnostic systems, has developed a new multi-barrier integrity diagnostics system – EmPulse®. The system quantitatively determines individual wall thickness in up to four concentric tubulars, ensuring long-term well performance in the most challenging high-chromium production environments.   The EmPulse system incorporates ‘ultra-fast’ sensor technology, three independent sensors, and ‘time-domain’ measurement techniques to capture EM signals rapidly and accurately in a wide range of pipe materials before the signals decay.   In three recent Middle East deployments – an operator witnessed ‘yard test’ in 28% chrome pipe with built-in mechanical defects, and two live wells – the EmPulse system correctly identified man-made defects and quantitatively determined the individual tubular thickness.   This successful validation in high-chromium tubulars brings important reassurances for Middle East operators in protecting well system integrity – providing accurate corrosion information and addressing a crucial information gap. The case of sustained annulus pressure [SAP] Figure 2: Spectral diagnostics survey revealing source of SAP behind casing at X540m where the cement map indicates ‘good cement’. Another major challenge to Middle East well system integrity is that of SAP – pressure in any well annulus that rebuilds when bled down.   Reasons for SAP can vary but are often due to weaknesses in the cement during completion; cement degradation due to thermal and pressure loading; leaking tubing connections or wellhead seals; and corrosion. According to a 2013 SPE webinar on wellbore integrity [Paul Hopmans], out of ~1.8 million wells worldwide, a staggering 35% have SAP, with many Middle East fields facing varying levels.   Wells with SAP need to be carefully managed and production can be adversely affected or halted. SAP can also cause further damage to the well system, potentially resulting in the failure of the production casing or outer casing strings, and well blowouts.   While many operators are addressing SAP through new well designs and barriers, and better quality control over cementing – with existing wells they are having to rely on surface data – fluid sampling and bleed-off/build-up data, for example – to investigate the problem downhole.   There is also the challenge of being able to locate leaks and unwanted flowpaths behind multiple barriers, not clearly seen by conventional temperature and ordinary noise logs.   TGT’s spectral diagnostics technology locates leaks and flowpaths throughout the well system by tracking fluid movement behind pipes within several casing strings.   Spectral diagnostics utilise high-fidelity downhole sound recording systems to capture the frequency and amplitude of acoustic energy generated by liquids or gas moving through integrity breaches and restrictions such as cement channels, faulty seals and casing leaks. When coupled with surface data, the information can narrow down the range of remedial options available, and target leak repairs.   Spectral diagnostics include fast, high-precision temperature measurements to locate integrity breaches throughout the well system. High-precision temperature sensors respond more quickly than conventional sensors to the localised thermal changes caused by integrity failures, complementing acoustic measurements by providing a visual confirmation of leaks and flowpaths.   While conventional production logging measurements typically assess only high-rate first-barrier failures – the high-fidelity recording, sensitivity and clarity of spectral diagnostics enables the tracking of even low-rate leaks at very early stages behind multiple barriers, enabling timely intervention and prolonging well life. In the following example [figure 2], a water injector well experienced sustained B-annulus pressure, although the build-up rate did not exceed one bar a day – indicating a low-rate leak.   A cement bond survey indicated good cement bonding below X500m, and poor bonding above. Poor cement bonding is likely to provide flowpaths for fluid movement behind casing. Unfortunately, cement bond log indications of ‘good bonding’ don’t guarantee annulus integrity. Flowpaths can exist that remain unnoticed by the cement bond log.   A survey utilising TGT’s spectral diagnostics system was conducted and revealed fluid flow from the reservoir around X540m and channelling up the annulus through the ‘good bonding’ area.   The frequency spectrum pattern correlated with reservoir permeability and fluid-type profiles, suggesting gas being produced from these formations. The operator used the information to target a cement squeeze operation at the desired location in the well – restoring B-annulus integrity and eliminating the SAP. Evolving challenges, new technologies  As Middle East operators continue to face well integrity challenges, gaining a deeper insight into both well and reservoir dynamics is vital. Advanced well diagnostics systems are now available to allow this to be achieved.

Creating reservoir flow profiles can enable better well and field management decisions Article featured in Harts E&P   A completed well is a sophisticated industrial-scale plumbing system, designed to transport fluids between subsurface reservoirs and the surface safely, productively and profitably. Injectors transport fluids one way, and producers transport more valuable fluids the other. Well system fusion Before the insertion of this grand plumbing scheme into the earth, the targeted subsurface reservoir and the fluids contained within it existed for millennia in a state of relative equilibrium. However, when the human-made tubulars, cement sheath and other well completion elements were “fused” with the subsurface by the well construction processes, this stasis was dramatically transformed into a complex and turbulent dynamic state.   This fusion between the human-made materials of the well completion and the natural materials of the earth, together with the dynamic interplay that now exists between the two, is what TGT Oilfield Services calls the “total well system.”   The well system includes that previously elusive volume of earth that exists beyond the wellbore, in the outer periphery of the well completion and the cement sheath that surrounds it—the so-called “well-to-reservoir interface.” Understanding the behavior of fluids here, and specifically the “flow” of fluids, is crucial to understanding the productive behavior of the entire well system. This is one reason why TGT Oilfield Services developed through-barrier diagnostics, which reveal flow behavior throughout the well system, from the wellbore through the completion and to its outer extremities where it connects intimately with the reservoir. An imperfect world In a perfect world, the well completion behaves according to its design and transports the right fluids to and from the right place in the subsurface. Moreover, in the same perfect world, the reservoir surrenders or receives the right fluids, and the total well system delivers safely, productively and profitably according to plan.   However, imperfections corrupt this ideal relationship and forces conspire to undermine the system. Imperfect cement seals, degraded packers, worn out valves, corroded pipe, near wellbore fractures and other barrier failures collude to open unwanted flow paths throughout the well system. As a result, essential fluids are diverted, sustained annulus pressures can dangerously manifest and, ultimately, producers or injectors will not behave as expected or underperform. Water destination A classic example of this occurs in injector wells. Petroleum and reservoir engineers determine that if water is injected at a particular pressure, then subsurface target zones will receive a certain volume of water over time. If the predicted flow rate is not observed, then either something is wrong with the assumptions and calculations or something is wrong with the well system—or both. Even worse, the predicted flow rate might be within range, but the water might not be reaching the target. The latter scenario is particularly insidious because it may be weeks, months or longer before an alarm is raised.   TGT has diagnosed thousands of injector wells and, in the majority of cases, has revealed unwanted flow paths behind the production casing, under- and overperforming target zones, and “thief zones” that effectively “steal” water from its intended destination.   Consider the injection well case shown in Figure 1. Conventional borehole flow diagnostics using production logging techniques (PLTs) tell the operator that most of the injected water is reaching the top half of the target reservoir unit (A3), and the rest is entering the lower half (far right track labeled “borehole flow profile”). Injection well case However, through-barrier spectral diagnostics by TGT reveal the true picture of what is happening with the well system. In reality, only 25% of the injected water is entering the target reservoir unit. The rest is channeling upward to a shallower unit (A2) from 210.3 m (690 ft) to 158.5 m (520 ft), probably though an imperfect cement sheath behind casing. A smaller amount is channeling downward.   This is a serious issue from both a well and reservoir management perspective. Not only is the target reservoir not receiving enough water to fulfill the field injection strategy, but 75% of the injected water is being wasted and potentially causing water breakthrough issues at other wells, compounding the loss. This essential information directly impacts well performance and potentially fieldwide management decisions. Harnessing acoustic and thermal energy TGT’s spectral diagnostics harness acoustic and thermal energy to locate and quantify fluid flow behind well barriers, thereby providing a complete picture of flow dynamics and pathways throughout the well system. High-fidelity sound recordings and processing technology deployed downhole locate flow activity by capturing and analyzing the characteristics of sound energy generated by pressurized fluid passing through well system restrictions, such as cement channels and reservoir entry points.   The position and relative intensity of the resulting spectral signature indicate the precise locations of flow activity (see the middle track of Figure 1 labeled “spectral injection”). This information is then used together with other well system data to guide a powerful and unique flow modeling engine that transforms precise thermal profiles into flow rates. The result is a behind-casing reservoir flow profile, which can be used in combination with the borehole flow profile to enable better well management and field management decisions (see right-hand track labeled “reservoir flow profile”).   Well barrier imperfections exist in all well types, so similar “unwanted flow path” scenarios exist in production wells too. Water source The case shown in Figure 2 is a deviated production well exhibiting a very high water cut of greater than 90%. Identifying the source of high water cut is one of the most urgent priorities for petroleum and reservoir engineers to resolve.   Whereas the PLT-derived borehole flow profile can only measure flow entering the wellbore in front of the perforated interval (A2), the spectral signature map indicates significant flow activity behind casing at several other producing intervals, namely A3, A4 and A5, and to a lesser extent at A1. Given that these intervals are known to be water-filled, the operator can confidently conclude that more than 60% of the produced water is coming from these zones. Knowing the exact locations of the source, the operator can take appropriate action to seal off the unwanted flow paths. Deviated production well exhibiting a very high water cut of greater than 90% Good bond, bad seal In the case study, the operator concluded that water from these zones was channeling through an imperfect cement sheath. Even though the azimuthal cement map and cement bond log indicated that the cement sheath had good mechanical coverage and a good bond with the casing, the cement was not providing a hydraulic seal. This specific aspect underlines the importance of verifying both barrier condition and barrier sealing performance when deciphering flow dynamics around the well system and eliminating unwanted flow. Completing the picture Conventional technology, such as PLTs, helps operators understand flow dynamics within the wellbore. However, this information does not always align with what is happening beyond the wellbore—beyond casing and cement at the reservoir interface. Evaluating the well system with through-barrier diagnostics is the only way to understand what is happening in the well system. Armed with a complete picture, the operator can confidently make better decisions to ensure the well system delivers the right fluids to the right place, safely and profitably for the entire productive life of the well.

Creating reservoir flow profiles can enable better well and field management decisions. A completed well is a sophisticated industrial-scale plumbing system, designed to transport fluids between subsurface reservoirs and the surface safely, productively and profitably. Injectors transport fluids one way, and producers transport more valuable fluids the other. Well system fusion Before the insertion of this grand plumbing scheme into the earth, the targeted subsurface reservoir and the fluids contained within it existed for millennia in a state of relative equilibrium. However, when the human-made tubulars, cement sheath and other well completion elements were “fused” with the subsurface by the well construction processes, this stasis was dramatically transformed into a complex and turbulent dynamic state.   This fusion between the human-made materials of the well completion and the natural materials of the earth, together with the dynamic interplay that now exists between the two, is what TGT Oilfield Services calls the “total well system.”   The well system includes that previously elusive volume of earth that exists beyond the wellbore, in the outer periphery of the well completion and the cement sheath that surrounds it—the so-called “well-to-reservoir interface.” Understanding the behavior of fluids here, and specifically the “flow” of fluids, is crucial to understanding the productive behavior of the entire well system. This is one reason why TGT Oilfield Services developed through-barrier diagnostics, which reveal flow behavior throughout the well system, from the wellbore through the completion and to its outer extremities where it connects intimately with the reservoir. An imperfect world In a perfect world, the well completion behaves according to its design and transports the right fluids to and from the right place in the subsurface. Moreover, in the same perfect world, the reservoir surrenders or receives the right fluids, and the total well system delivers safely, productively and profitably according to plan.   However, imperfections corrupt this ideal relationship and forces conspire to undermine the system. Imperfect cement seals, degraded packers, worn out valves, corroded pipe, near wellbore fractures and other barrier failures collude to open unwanted flow paths throughout the well system. As a result, essential fluids are diverted, sustained annulus pressures can dangerously manifest and, ultimately, producers or injectors will not behave as expected or underperform. Water destination A classic example of this occurs in injector wells. Petroleum and reservoir engineers determine that if water is injected at a particular pressure, then subsurface target zones will receive a certain volume of water over time. If the predicted flow rate is not observed, then either something is wrong with the assumptions and calculations or something is wrong with the well system—or both. Even worse, the predicted flow rate might be within range, but the water might not be reaching the target. The latter scenario is particularly insidious because it may be weeks, months or longer before an alarm is raised.   TGT has diagnosed thousands of injector wells and, in the majority of cases, has revealed unwanted flow paths behind the production casing, under- and overperforming target zones, and “thief zones” that effectively “steal” water from its intended destination.   Consider the injection well case shown in Figure 1. Conventional borehole flow diagnostics using production logging techniques (PLTs) tell the operator that most of the injected water is reaching the top half of the target reservoir unit (A3), and the rest is entering the lower half (far right track labeled “borehole flow profile”). Injection well case However, through-barrier spectral diagnostics by TGT reveal the true picture of what is happening with the well system. In reality, only 25% of the injected water is entering the target reservoir unit. The rest is channeling upward to a shallower unit (A2) from 210.3 m (690 ft) to 158.5 m (520 ft), probably though an imperfect cement sheath behind casing. A smaller amount is channeling downward.   This is a serious issue from both a well and reservoir management perspective. Not only is the target reservoir not receiving enough water to fulfill the field injection strategy, but 75% of the injected water is being wasted and potentially causing water breakthrough issues at other wells, compounding the loss. This essential information directly impacts well performance and potentially fieldwide management decisions. Harnessing acoustic, thermal energy TGT’s spectral diagnostics harness acoustic and thermal energy to locate and quantify fluid flow behind well barriers, thereby providing a complete picture of flow dynamics and pathways throughout the well system. High-fidelity sound recordings and processing technology deployed downhole locate flow activity by capturing and analyzing the characteristics of sound energy generated by pressurized fluid passing through well system restrictions, such as cement channels and reservoir entry points.   The position and relative intensity of the resulting spectral signature indicate the precise locations of flow activity (see the middle track of Figure 1 labeled “spectral injection”). This information is then used together with other well system data to guide a powerful and unique flow modeling engine that transforms precise thermal profiles into flow rates. The result is a behind-casing reservoir flow profile, which can be used in combination with the borehole flow profile to enable better well management and field management decisions (see right-hand track labeled “reservoir flow profile”).   Well barrier imperfections exist in all well types, so similar “unwanted flow path” scenarios exist in production wells too. Water source  The case shown in Figure 2 is a deviated production well exhibiting a very high water cut of greater than 90%. Identifying the source of high water cut is one of the most urgent priorities for petroleum and reservoir engineers to resolve.   Whereas the PLT-derived borehole flow profile can only measure flow entering the wellbore in front of the perforated interval (A2), the spectral signature map indicates significant flow activity behind casing at several other producing intervals, namely A3, A4 and A5, and to a lesser extent at A1. Given that these intervals are known to be water-filled, the operator can confidently conclude that more than 60% of the produced water is coming from these zones. Knowing the exact locations of the source, the operator can take appropriate action to seal off the unwanted flow paths. Deviated production well exhibiting a very high water cut of greater than 90% Good bond, bad seal In the case study, the operator concluded that water from these zones was channeling through an imperfect cement sheath. Even though the azimuthal cement map and cement bond log indicated that the cement sheath had good mechanical coverage and a good bond with the casing, the cement was not providing a hydraulic seal. This specific aspect underlines the importance of verifying both barrier condition and barrier sealing performance when deciphering flow dynamics around the well system and eliminating unwanted flow. Completing the picture Conventional technology, such as PLTs, helps operators understand flow dynamics within the wellbore. However, this information does not always align with what is happening beyond the wellbore—beyond casing and cement at the reservoir interface. Evaluating the well system with through-barrier diagnostics is the only way to understand what is happening in the well system. Armed with a complete picture, the operator can confidently make better decisions to ensure the well system delivers the right fluids to the right place, safely and profitably for the entire productive life of the well.

New fracture flow diagnostics help operators elevate fracture performance  In recent years, the Permian basin is been the most prolific shale play in the US. Production in this area increased to 3.8 million barrels by 2019, representing almost 70% of the whole US production growth from 2011 to 2019 according to International Energy Agency (IEA). The impressive aspect of this achievement is that the growth has not stopped. On the contrary, the Permian is expected to continue growing and is estimated to achieve up to 5.8 million barrels by the end of 2023.   Such impressive growth doesn’t come easy. Significant advances in drilling, completing and multi-stage fracturing will continue to drive production increases. But evaluating the performance of fracturing programmes and the wells they deliver is key to optimising resources and ensuring maximum return on investment. Conventional diagnostics [such as production logging tools or ‘PLT’s’] can’t provide all the insights required to ensure the operator is achieving the best returns. This article focuses on the challenges faced when assessing unconventional reservoirs in terms of production, and features a new diagnostic capability introduced by TGT to evaluate the flow performance of hydraulically fractured wells, stage-by-stage. The new diagnostic product is aptly called ‘Fracture Flow’.   Operators have been drilling aggressively and pushing the boundaries of hydraulic fracturing beyond conventional standards compared to other plays. The drilled length of lateral sections has been constantly boosted, adding more footage as well as more production stages. The ultimate objective is to penetrate deep into the target formation increasing the area of contact with the specific reservoir or formation making the well, its completion and the reservoir one dynamic production system.   Champions of this approach include a Houston-based operator that recently drilled such a well at the Wolfcamp. The completion included a lateral section of more than 17,900 ft running through the Spaberry formation. The completed well had a total measured depth exceeding 24,500 ft with a customised completion design and fracking treatment. The completion included more than 50-stages and sand was pumped along more than 2,200 ft of reservoir to increase the well productivity.   These extended laterals have been engineered to optimise production performance and leverage improvements in drilling, fracking treatments and completion designs. The operators have overcome the number of well construction challenges and have quickly moved up a steep learning curve.   Like the challenges encountered with well construction, the Permian basin faces its own challenges. Following such an extensive multistage hydraulic fracturing programme, the wells are brought onstream at high initial production rates. But most of these extended-lateral producers tend to decline dramatically over a very short period. To help combat this challenge, and many others, TGT has developed a number of application-specific diagnostic products using its ‘True Flow System’ to quantitively evaluate flow dynamics throughout the entire well system – from reservoir to the wellbore, and the dynamic interplay between the two.   When talking about a hydraulic fracturing job, we all know the importance of the programme design prior to execution. During this phase, sophisticated software is utilised to model and optimise the fracturing programme, taking into consideration multiple variables. These variables include formation properties, lithology, depth, mechanical stresses and other parameters that can affect the final outcome. Another important consideration is the formulation of the hydraulic fracturing fluid. This fluid is normally comprised of sand (or proppant), gels (foam or sleek-water) and additives that are pumped downhole following the job design to prop open the induced fractures and maximise the extension of the fracture in terms of length, height and aperture as well as the integrity of the fractured conduit itself, so hydrocarbons can flow unabated.   TGT’s diagnostic ‘Fracture Flow’ product is able to locate and evaluate fracture inflows and quantify inflow profiles in hydraulically fractured wells. The product is delivered by our analysts using the ‘True Flow System’, which combines several technology platforms – Chorus (acoustic), Cascade (thermal), Indigo (multisense) and Maxim (digital workspace), to acquire, interrogate and analyse the acoustic spectra and temperature changes generated by the hydrocarbons or any other fluid flowing from the reservoir through active fractures and into the completion. This diagnostic capability goes beyond conventional flow measurement techniques that generally stop sensing at the wellbore and are therefore unable to quantify flow within the reservoir itself.   The Fracture Flow product extract shown in figure-1 represents the diagnosis of a hydraulically fractured oil producer with >80 degrees deviation. The reservoir has a gross thickness of approximately 1,200 ft and is fully cased. To celebrate, TGT invited employees, customers, and business partners to an evening which relived the company’s scientific breakthroughs using acoustic, thermal and electromagnetic energy to reveal unique answers within and beyond the well bore.   Dr. Arthur Aslanyan, TGT’s Co-Founder commented, “It gave me great pride to attend the event and celebrate the company's 20th anniversary. We have come a long way since we first started the business. We are very excited about our future as the company continues to thrive”.   The event was attended by Saad Bargach, TGT Chairman and LimeRock Partners -private equity investors.   Hegazi continued, “Looking to our future, TGT is releasing several lines of new technologies and applications in coming months to further cement our position as pioneers of Through-Barrier Diagnostics. Our patent technology developments coupled with our unrivalled Geoscience organisation and global footprint, provide unique and reliable diagnostic services to our customers. This has been key in maintaining our fast growth trend and industry reputation. I am confident this foundation along with our excellent teams, will continue to fuel our growth for many years to come. Figure-1 ‘Fracture Flow’ diagnostics compare fractured intervals [blue] to main producing intervals [green] at different choke sizes in order to evaluate the true effectiveness of hydraulic fracturing programmes and maximise well performance The operator’s objectives in this case were to evaluate the post-fracture performance of three zones, and in particular:   - Compare the effectiveness of fractured stages by assessing the production contribution from each fractured interval - Identify crossflow or behind-casing communication - Increase production efficiency by identifying the optimum production choke for this well system.   The results revealed by the Fracture Flow analysis clearly revealed that the fractured intervals (figure-1 – blue coding) were not contributing fully to production in their entirety. Furthermore, it identified exactly the active zones and where the main production was coming from (figure-1 green coding). Fracture Flow revealed that only 62%, 59% and 56% of each zone was actually producing at the outset.   The Fracture Flow analysis also indicated that there were no crossflows among the three zones which was another key finding from an integrity perspective.   Thirdly, the Fracture Flow diagnostic programme helped to determine the optimal choke size required to ensure that the fractured zones were contributing at maximum rate.   TGT work in close collaboration with operators using Fracture Flow to help them reach their frac evaluation objectives; locate effective fracture inflows; quantify inflow profiles; and assess the effectiveness of fracture programmes, helping to optimise future programmes and maximise return on investment.   TGT is an international diagnostics company that specialises in ‘through-barrier diagnostics’ for the oilfield. Our Houston-based operation provides unique ‘True Flow’ and ‘True Integrity’ diagnostics to operators throughout the United States, including the Permian. We are also working actively in deep water Gulf of Mexico, Latin America and other major basins around the globe. Our diagnostics help operators make better decisions so they can manage wells safely, productively and profitably. tgtdiagnostics.com

TGT’s 11th Student Mathematical Modelling and Information Technologies (SMIT) conference was held on 25-26 April at our Technology Centre, Kazan.   SMIT provides top engineering students with the opportunity to engage with leading industry experts. The conference mainly focuses on ‘best practice’ for modelling physical processes and the implementation of new mathematical signal processing techniques used in the oil and gas sector plus other industries.   University students registered their interest by submitting an abstract on www.smit-conference.com.   Abstracts were reviewed by a panel of academic society representatives and industry professionals. At the conference each participant was invited to deliver their 15-minute presentation. The best work was published in peer-reviewed scientific journals which is recognised by the State Commission for Academic Degrees and Titles. "We are an innovative company, constantly striving to advance our well flow and well integrity services. Attracting, developing and retaining top talent is critical to our culture and future”, comments Maksim Gladkiy, Deputy Managing Director, TGT Oilfield Services Technology Centre.   “Together with our partners, our goal is to help young talented students to be discovered and provide a platform for them to launch their careers”, adds Maksim. “SMIT provides an excellent opportunity for participants to share experiences and ideas; and to be reviewed by experts in a real-life industrial application.” adds Maksim.