New ‘real-time’ technology expands convenience, flexibility and fidelity of powerful well system diagnostics for oilfield customers TGT announced today the release of its real-time Indigo platform, significantly expanding the range of benefits brought by its family of powerful through-barrier diagnostic systems. The new real-time technology enables well data to be viewed and analysed at surface during the execution of well diagnostic programmes without compromising on measurement fidelity. This will bring several benefits to customers, including improved data quality, enhanced intervention efficiency and faster remediation decisions.   Ken Feather, TGT’s Chief Marketing Officer commented, “Real-time data isn’t new to the oil industry, but currently available transmission systems couldn’t meet our exacting data quality standards—so we developed and built our own high-fidelity system. In doing that we have taken conveyance and decision-making flexibility to an entirely new level for our customers, with no compromise on measurement quality. As a result, we expect the popularity of our diagnostic systems and products to expand even further.”   TGT creates all its own hardware and software in-house and follows a strict philosophy of ‘fidelity’ in the design and manufacturing of its diagnostic sensor technology and instruments. This philosophy is clearly embodied in its ‘Indigo’ platform of complementary sensors and auxiliary equipment. Indigo technology is distinctly ‘low noise’ and custom-built to operate perfectly with TGT’s through-barrier suite. The new real-time capability is particularly relevant to TGT’s acoustic-based ‘spectral’ and electromagnetic-based ‘EmPulse’ diagnostic systems, which lead the industry in diagnosing flow and integrity dynamics within oil and gas wells, helping operators to improve well performance.   Traditionally, through-barrier diagnostics are performed using ‘memory-mode’ deployment. With a track record of 20-years and an efficiency of more than 99%, TGT’s memory-mode deployment remains a flexible and popular choice across the industry. With this approach, diagnostic information is accessed when the measuring instrument is retrieved from the well. However, with real-time access, data can be viewed during the diagnostic intervention and streamed remotely from the wellsite enabling a host of benefits, such as dynamically adjusting the acquisition program, and making faster decisions.   Artem Buharaev, TGT’s head of Indigo development also commented, “We have overcome many technical challenges in commercialising our real-time Indigo platform. Existing data transmission technology available within our industry generates unacceptable levels of acoustic and electromagnetic [EM] ‘noise’, that would otherwise degrade our highly-sensitive sound-based and EM-based measurements, so we developed our own design that was both ‘quiet’ and fast.”   The real-time system comprises of a downhole Indigo modem module and a surface interface unit that enables two-way communication between surface recording equipment and the downhole instruments. Testing Indigo's 'high fidelity' platformReal-time Indigo platform structure Indigo is a fully integrated ‘high-fidelity’ platform of wellbore production sensors, communication, navigation, memory and power supply modules that are designed to work seamlessly with TGT’s flagship through-barrier diagnostic systems. Engineered and built completely in-house, all Indigo modules have been designed to eliminate the possibility of interference with TGT’s high-performance acoustic and electromagnetic sensors. Conventional industry wellbore instruments contain components and circuitry that generate rogue acoustic and electromagnetic [EM] noise that can interfere with measurements, effectively compromising the data analysis. Our customers rely on the fidelity of our diagnostic insights, so it’s important that our measurements only capture true well system behaviour, which is why we developed Indigo.   Indigo enables both memory-mode and real-time data acquisition from production sensors housed in titanium. Measurements include high-precision temperature, pressure, gamma ray, casing collar locator, fluid capacitance, fluid resistivity and heat-exchange. Fullbore and continuous flow spinner modules are added to provide complete wellbore flow diagnostics.

Article featured in Oilfield technology   Well integrity management is a full lifecycle process adopted from the well design and construction phase right through to abandonment.   Yet, just as well diagnostics should take place at the outset of the well life – with even new completions sometimes containing flaws such as leaking connections and poor cement isolation – there is an increased focus today on routine integrity management, as well systems age and move towards abandonment. Revitalising aging wells In many regions of the world, increasing demands are being placed upon ageing well stock as operators seek to extend field life. Significant remaining reserves are the prize and technology-enabled process innovations, such as drilling multi-lateral extensions from existing wells, allow this to happen.   In the Middle East, for example, more than 70% of the ~800 Middle East platforms and associated well-stock are more than 25 years old, and in the North Sea, according to the UK Oil & Gas Authority, there remain 20 billion barrels of oil and gas resources still to be recovered on the UK Continental Shelf – a region that has been continually developed for nearly 50 years.   In such cases, whilst multi-lateral well components are new, the original wellhead, conductor and production casings have remained the same.   However, whereas previously such well stock survived through regular maintenance of the more accessible elements of the well, today more powerful well integrity diagnostics are required to monitor casing strings, tubulars and other crucial well components throughout the well system – from inside the tubing.   This article will look at how this is being achieved with through-barrier diagnostics. Through-barrier diagnostics Through-barrier diagnostics, a capability developed and perfected by TGT since it was founded two decades ago, is a valuable resource in proactive integrity management today because it evaluates critical aspects of the entire well system from inside the tubing.   Through-barrier diagnostic systems can sense dynamic well behavior and properties throughout the well, helping operators to evaluate the condition and performance of critical well components from inside the tubing.   By cleverly harnessing heat, acoustic and electromagnetic [EM] energy, through-barrier diagnostics can determine the wall thickness of individual tubulars, and locate and quantify fluid movements behind the pipe.   Two key areas where through-barrier diagnostics are having a major impact today are in tracking corrosion and sustained annulus pressure [SAP]. Tackling corrosion in the rise of chrome In some regions, downhole conditions are highly corrosive and well completions are constantly under attack from aggressive fluids, such as hydrogen sulphide, carbon dioxide and chloride. The degradation of wellbore tubulars and metal barriers is a major threat to well integrity.   On the Arabian Peninsula for example, formations such as Rus, Simsima, and Daman can cause severe corrosion of the outer well casing strings. Corrosive fluids from the aquifers can reach the outer casing surface because of integrity breaches in the outer well annulus. This is because either the outer cement sheath has degraded over time, or the initial cementing operation may have been compromised by the inability of formations to support pressure, resulting in cement losses and an imperfect seal.   In such cases, comprehensive and regular inspection is required by operators to determine whether corrosion is taking place at an acceptable rate, or if intervention and remedial action is required. To this end, the well diagnostics approach must provide quantitative information about multiple casing strings efficiently and reliably.   Yet, previously few operators were able to track corrosion to this level of detail and across all pipe strings.   To address this challenge, TGT has developed EmPulse® – a multi-barrier pipe inspection system capable of providing barrier-by-barrier visualisation of the tubulars that make up the well operating envelope, reliably and proactively. Ultra-fast EM-based sensor technology and time-domain measurements, coupled with advanced Maxwell processing, enable the system to quantify metal loss in up to four barriers independently and accurately.   In this way, it delivers sensitive and fast response measurements, bringing with it significant advantages over the frequency-based measurements offered by ordinary pipe inspection systems. Frequency-based measurements are also unable to distinguish the thickness of individual barriers and as a result provide limited information about barrier condition or the precise location of failures.   Another challenge EmPulse is addressing is that of chrome.   In a bid to pre-empt corrosion, many operators are opting for alternative steels and corrosion resistant materials, such as chrome, nickel and molybdenum. However, such materials pose even more challenges to ordinary pipe inspection systems with the decrease in ferrous content causing EM signals to decay too quickly for an effective measurement.   Yet, recent deployments in the Middle East have shown that EmPulse can again quantitatively determine the individual tubular thickness of up to four concentric barriers, even when there are high amounts of chrome in the tubulars.   In one Middle East operator-witnessed ‘yard test’ consisting of a 28% chrome pipe with built-in mechanical defects, the high-speed EM sensor technology within the EmPulse system correctly identified the man-made problems in a controlled environment.   Additional operations took place in two live Middle East wells in a very high hydrogen sulphide gas production scenario with 28% chrome tubulars. In this case, the EmPulse system again functioned as planned, and recorded the status of three concentric well barriers. A multi-finger caliper recording also confirmed the electromagnetic results for the condition of the inner pipe.   As operators endeavor to protect well integrity in challenging production environments and require versatility over tubular materials, it’s good to see that through-barrier diagnostics – backed up by many of the industry’s leading well log analysts – are meeting these challenges and providing a complete end-to-end well diagnostics solutions. Cementing and sustained annulus pressure (SAP) Two other challenges to well integrity today – both interlinked – are that of well cementing and sustained annulus pressure [SAP].   As operators look to deeper and longer reach wells, cementing techniques and sealing abilities have been pushed to the limit. According to the Society of Petroleum Engineers [SPE], at least 25-30% of wells are estimated to have annular pressure problems with cementing being one of the root causes. One outcome of this is SAP – pressure in any well annulus that rebuilds when bled down.   SAP is often the result of weaknesses in the cement during completion; or 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.   So how can well cementing and SAP be addressed?   To date, conventional means of tracking poor cementing and SAP is through surface measurements, such as fluid sampling, bleed-off/build-up data and downhole measurements such as ‘cement bond logs’, temperature and ordinary noise logs. This, however, only provides limited information and may be unable to locate leaks and unwanted flowpaths behind multiple barriers – especially when the leak rate is low.   To address this information gap, TGT’s ‘spectral diagnostics’ technology tracks fluid movement behind pipes from within several casing strings. This is achieved using high-fidelity downhole sound analysis systems to capture the frequency and amplitude of acoustic energy generated by liquids or gas moving through integrity breaches and restrictions. Complementing this, spectral diagnostic systems utilise high-precision temperature measurements to help locate integrity breaches throughout the well system.   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, thereby enabling timely intervention.   In 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, likely to provide flowpaths for fluid movement behind casing.   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 incorrectly assumed ‘good bonding’ area.   The frequency spectrum pattern correlated with reservoir permeability and fluid-type profiles, suggesting gas was 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. Figure 2 – Information from spectral diagnostics in a water Injector well Spectral diagnostics to abandon wells securely Spectral diagnostics can also play an important role in ensuring that wells are properly sealed during abandonment, especially with respect to unwanted fluid flow along the outer boundaries of the well system to surface – clearly a situation the operator wants to eliminate.   Operators perform through-barrier spectral diagnostics prior to abandonment to indicate the integrity status of the entire well system, and reveal where special remediation measures need to take place to seal the well properly and permanently. Diagnostics are also performed post-abandonment to validate that there is no unwanted fluid flow taking place and that the well is secure.   The well shown in figure 3 was part of an abandonment campaign where the operator observed sustained annulus pressure building at a rate of 0.1 bars per day in the C-annulus and 5 bars per day in the B-annulus. The maximum pressures in B-annulus were 35 bars while in C-annulus it was only 3.2 bars.   Multiple survey and plug/section milling stages were executed to abandon the well and each time through-barrier spectral diagnostics aided in targeting the plug intervals and verifying the integrity of the plug.   After the third stage, the sustained annulus pressure was eliminated in both annuli and spectral data confirmed that the unwanted flow in the outer annuli had been abated. In figure 3, one can see that the acoustic frequency-amplitude spectrum seen at stages 1 and 2 reveal zones of upward gas migration behind casing. The acoustic spectrum seen after stage 3 confirm that the gas migration had been stopped [the small acoustic response is due to residual gas].   As a result, the operator could depart from the well confident that the well was totally secure. Figure 3—Spectral diagnostics were performed during the three stages of abandonment for this well, helping the operator target special remediation measures pre-abandonment and validating integrity post-abandonment. Effective diagnostics throughout the well system Well integrity is all about ensuring that the right fluids connect safely and productively via the wellbore to the surface and don’t stray along unwanted flowpaths inside or outside the well system.   Operators select through-barrier diagnostics to deliver the crucial information they need to ensure well system integrity throughout the well lifecycle. It is these technology innovations supported by the skills and experience of TGT’s experts and others that are leading the way and reshaping well integrity management as we know it.

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. Article featured in Oil and Gas News   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. 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.

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.

Healthy wells Article featured in Oil and Gas Middle East   Proactive integrity management is a key focus area for exploration and production operators, and rightly so. Well integrity is fundamental to enabling maximum well system performance, and minimising cost and risk for the operator.   A well is usually delivered intact when new but issues like leaking connections or poor cement isolation can exist from the start and these of course need immediate and regular integrity diagnostics surveillance.   Then, as the well becomes exposed to harsh working conditions underground over many years, integrity breaches will occur, with these needing diagnosis and addressing early on. Inside the tubing diagnostics Through-barrier diagnostic systems – a capability TGT scientists and engineers have been pioneering for years – are vital for this task as they can evaluate most of the well system from inside the tubing.   Through-barrier diagnostic systems sense dynamic well behaviour and certain well properties behind well barriers – and consequently evaluate the condition and performance of the well system from inside the tubing. Such systems can determine the wall thickness of individual tubulars in up to four concentric pipe strings to track corrosion in each pipe. They can also locate fluid movement behind the pipe – essential in determining annulus integrity or locating barrier leaks.   Through-barrier diagnostic systems cleverly harness heat, acoustic and electromagnetic [EM] energy to perform certain measurements downhole and engage sophisticated processing and modelling to transform these measurements into insightful and useable answers.   It’s important, however, that through-barrier diagnostics keep up with current well integrity challenges. High-chrome tubulars are increasingly prevalent in the Middle East as a means of combatting corrosion but also challenging for ordinary EM well inspection systems to operate, due to a decrease in ferrous content and conventional EM signals decaying too quickly. High chrome deployments With this in mind, TGT recently conducted three successful high-chrome deployments with its EmPulse well inspection system – one a yard test with a 28% chrome pipe with built-in mechanical defects, and the two others live wells with high hydrogen sulphide and 28% chrome tubulars.   In the first case, the high-speed EM sensor technology and ‘time-domain’ measuring techniques correctly identified man-made defects and in the two live wells they recorded the status of three concentric well barriers.   Another well integrity challenge is cementing – particularly in deeper and longer reach wells – where cementing techniques and sealing abilities are being pushed to the limit. In such cases, ‘spectral diagnostics’ is a technology that tracks fluid movement behind pipes within several casing strings and identifies leaks and flowpaths.   Key to spectral diagnostics is its ability to utilise high-fidelity downhole sound analysis systems to capture the frequency and amplitude of acoustic energy generated by liquids or gas moving through integrity breaches and restrictions. Understanding well integrity While the meaning of ‘well integrity’ is often debated, it has one unifying principle – that of containment – ensuring that the right fluids connect safely and productively via the wellbore to surface, and that they don’t stray along unwanted flowpaths either inside, or worse still outside the well system.   Since most integrity failures happen behind tubing or casing, it’s incumbent upon through-barrier diagnostics to deliver the well system insights that Middle East operators need to ensure safe and productive operations. It’s reassuring to know that technologies are evolving to meet these challenges

Healthy Wells  Proactive integrity management is a key focus area for exploration and production operators, and rightly so. Well integrity is fundamental to enabling maximum well system performance, and minimising cost and risk for the operator.   A well is usually delivered intact when new but issues like leaking connections or poor cement isolation can exist from the start and these of course need immediate and regular integrity diagnostics surveillance.   Then, as the well becomes exposed to harsh working conditions underground over many years, integrity breaches will occur, with these needing diagnosis and addressing early on. Inside the tubing diagnostics Through-barrier diagnostic systems – a capability TGT scientists and engineers have been pioneering for years – are vital for this task as they can evaluate most of the well system from inside the tubing.   Through-barrier diagnostic systems sense dynamic well behaviour and certain well properties behind well barriers – and consequently evaluate the condition and performance of the well system from inside the tubing. Such systems can determine the wall thickness of individual tubulars in up to four concentric pipe strings to track corrosion in each pipe. They can also locate fluid movement behind the pipe – essential in determining annulus integrity or locating barrier leaks.   Through-barrier diagnostic systems cleverly harness heat, acoustic and electromagnetic [EM] energy to perform certain measurements downhole and engage sophisticated processing and modelling to transform these measurements into insightful and useable answers.   It’s important, however, that through-barrier diagnostics keep up with current well integrity challenges. High-chrome tubulars are increasingly prevalent in the Middle East as a means of combatting corrosion but also challenging for ordinary EM well inspection systems to operate, due to a decrease in ferrous content and conventional EM signals decaying too quickly. High chrome deployments With this in mind, TGT recently conducted three successful high-chrome deployments with its EmPulse well inspection system – one a yard test with a 28% chrome pipe with built-in mechanical defects, and the two others live wells with high hydrogen sulphide and 28% chrome tubulars.   In the first case, the high-speed EM sensor technology and ‘time-domain’ measuring techniques correctly identified man-made defects and in the two live wells they recorded the status of three concentric well barriers.   Another well integrity challenge is cementing – particularly in deeper and longer reach wells – where cementing techniques and sealing abilities are being pushed to the limit. In such cases, ‘spectral diagnostics’ is a technology that tracks fluid movement behind pipes within several casing strings and identifies leaks and flowpaths.   Key to spectral diagnostics is its ability to utilise high-fidelity downhole sound analysis systems to capture the frequency and amplitude of acoustic energy generated by liquids or gas moving through integrity breaches and restrictions. Understanding well integrity While the meaning of ‘well integrity’ is often debated, it has one unifying principle – that of containment – ensuring that the right fluids connect safely and productively via the wellbore to surface, and that they don’t stray along unwanted flowpaths either inside, or worse still outside the well system.   Since most integrity failures happen behind tubing or casing, it’s incumbent upon through-barrier diagnostics to deliver the well system insights that Middle East operators need to ensure safe and productive operations. It’s reassuring to know that technologies are evolving to meet these challenges

The company’s vision and motivator is the thirst for a greater knowledge of the well system, which combines the well completion and reservoir TGT Oilfield Services, the market leader in through-barrier diagnostics for the oilfield, has grown year-on-year even during the downturn and the company expects to see an improvement in both activity levels and pricing as the industry stabilises further.   "Despite the drop in oil price, the demand for TGT diagnostic services grew significantly. Our focus on technology and applications that diagnose the performance and integrity of existing wells is exactly what our clients needed during the tough budget years.   "We expect that need to continue. We protect our market share and growth by continuing to fund technology development despite the market climate. Customers recognise the depth of our technical and sub surface knowledge, which has been built up over the last 20 years," says Maged Yassin, business unit manager, TGT Saudi Arabia. The company’s vision and motivator is the thirst for a greater knowledge of the well system, which combines the well completion and reservoir. This speaks for itself when one considers that more than a third of its headcount is dedicated to R&D and technology development, says Yassin.   Recently, TGT migrated its sensors to a custom-built ‘low-noise’ hardware – Indigo – designed to operate at ‘low noise’ so not to interfere with its acoustic-based ‘spectral’ and electromagnetic-based ‘EmPulse’ diagnostic systems.   Additionally, the company added a real-time capability to its fleet of through-barrier diagnostic systems. The new real-time technology enables well data to be viewed and analysed at surface during the execution of well diagnostic programmes without compromising on measurement fidelity. "We never stop, continuously improving our services and our offerings," says Yassin.   TGT provides a wide range of through-barrier diagnostics. Patented technologies are deployed on any conveyance and sense beyond the well bore to answer multiple reservoir flow and well integrity questions. The company offers these services in Saudi Arabia via in-country assets, geoscience and advanced interpretation as well as business development and field operations. TGT was founded on research and development. "Our technologies include advanced flow profiling deep into the reservoir, unconventional and fracture flow, multi annuli leak detection and multi barrier corrosion among others. We pride ourselves not only on equipment technology but also advanced geoscience and interpretation capabilities," he says.   "Saudi Arabia represents one of our most significant markets," he says. TGT has in place a stringent Saudisation development plan and technical knowledge transfer through academia alliances. Referring to Saudi Aramco’s In-Kingdom Total Value Add (IKTVA) plan, he says the published target is 35 per cent by 2020. "TGT will comply with or exceed these targets on all fronts (equipment, human capital, safety and environment) as we establish ourselves further in the kingdom," he asserts. On the company’s relationship with Saudi Aramco, he says Aramco is a highly sophisticated organisation, with a strong emphasis on strategic planning to optmise operations.   "Our relationship, like with all our customers, is built on a foundation technical competence, respect for the accuracy of the results we provide and our service delivery. We ensure we understand the customer’s challenges before designing a bespoke programme to determine the answers they seek," he says.   Referring to business growth, Yassin says business has gradually improved in the last two years in terms of activity.   Pricing of services remains a challenge. The significant rebound of oil price will soon cascade to the market to ensure continued technology development and growth.   "TGT Saudi Arabia is one of our key dedicated business units, supported by a solid global infrastructure. While we continue to expand our global footprint, we will ensure we stay focused on our customers, proving the quality of our diagnostic results, striving to set ourselves apart from our competition," he says.

The company’s vision and motivator is the thirst for a greater knowledge of the well system, which combines the well completion and reservoir TGT Oilfield Services, the market leader in through-barrier diagnostics for the oilfield, has grown year-on-year even during the downturn and the company expects to see an improvement in both activity levels and pricing as the industry stabilises further.   "Despite the drop in oil price, the demand for TGT diagnostic services grew significantly. Our focus on technology and applications that diagnose the performance and integrity of existing wells is exactly what our clients needed during the tough budget years.   "We expect that need to continue. We protect our market share and growth by continuing to fund technology development despite the market climate. Customers recognise the depth of our technical and sub surface knowledge, which has been built up over the last 20 years," says Maged Yassin, business unit manager, TGT Saudi Arabia. The company’s vision and motivator is the thirst for a greater knowledge of the well system, which combines the well completion and reservoir. This speaks for itself when one considers that more than a third of its headcount is dedicated to R&D and technology development, says Yassin.   Recently, TGT migrated its sensors to a custom-built ‘low-noise’ hardware – Indigo – designed to operate at ‘low noise’ so not to interfere with its acoustic-based ‘spectral’ and electromagnetic-based ‘EmPulse’ diagnostic systems.   Additionally, the company added a real-time capability to its fleet of through-barrier diagnostic systems. The new real-time technology enables well data to be viewed and analysed at surface during the execution of well diagnostic programmes without compromising on measurement fidelity. "We never stop, continuously improving our services and our offerings," says Yassin.   TGT provides a wide range of through-barrier diagnostics. Patented technologies are deployed on any conveyance and sense beyond the well bore to answer multiple reservoir flow and well integrity questions. The company offers these services in Saudi Arabia via in-country assets, geoscience and advanced interpretation as well as business development and field operations. TGT was founded on research and development. "Our technologies include advanced flow profiling deep into the reservoir, unconventional and fracture flow, multi annuli leak detection and multi barrier corrosion among others. We pride ourselves not only on equipment technology but also advanced geoscience and interpretation capabilities," he says.   "Saudi Arabia represents one of our most significant markets," he says. TGT has in place a stringent Saudisation development plan and technical knowledge transfer through academia alliances. Referring to Saudi Aramco’s In-Kingdom Total Value Add (IKTVA) plan, he says the published target is 35 per cent by 2020. 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 will comply with or exceed these targets on all fronts (equipment, human capital, safety and environment) as we establish ourselves further in the kingdom," he asserts. On the company’s relationship with Saudi Aramco, he says Aramco is a highly sophisticated organisation, with a strong emphasis on strategic planning to optmise operations.   "Our relationship, like with all our customers, is built on a foundation technical competence, respect for the accuracy of the results we provide and our service delivery. We ensure we understand the customer’s challenges before designing a bespoke programme to determine the answers they seek," he says.   Referring to business growth, Yassin says business has gradually improved in the last two years in terms of activity.   Pricing of services remains a challenge. The significant rebound of oil price will soon cascade to the market to ensure continued technology development and growth.   "TGT Saudi Arabia is one of our key dedicated business units, supported by a solid global infrastructure. While we continue to expand our global footprint, we will ensure we stay focused on our customers, proving the quality of our diagnostic results, striving to set ourselves apart from our competition," he says.

Diagnostics Behind the Barriers A wide range of tubulars are tested in the EmPulse characterization facility at TGT Oilfield Services’ technology center in Kazan, Russia, to ensure accurate metal wall thickness measurements. Wall thickness is an indicator of barrier condition.   A wide range of tubulars are tested in the EmPulse characterization facility at TGT Oilfield Services’ technology center in Kazan, Russia, to ensure accurate metal wall thickness measurements. Wall thickness is an indicator of barrier condition.   Alongside those efforts, companies are increasingly recognizing the value of using diagnostic systems to detect issues that compromise well barriers. “Because most well integrity problems occur in the outer periphery of the well, behind barriers such as tubulars and cement, a process for sensing and locating leaks, or flow paths along the annulus, is crucial,” said Ken Feather, Chief Marketing Officer, TGT Oilfield Services. The company provides “through-barrier” diagnostics using thermal, electromagnetic (EM) and acoustic energy.   The EmPulse multi-tube imaging system produces tube integrity diagnostics. Measurements performed from within the 3 1/2-in. production tubing show significant corrosion in the 13 3/8-in. casing, quantifying metal loss of 34% and 44% in the third barrier.   The EmPulse multi-tube imaging system produces tube integrity diagnostics. Measurements performed from within the 3 1/2-in. production tubing show significant corrosion in the 13 3/8-in. casing, quantifying metal loss of 34% and 44% in the third barrier.   “Barriers, such as tubulars, cement, elastomers, packers and valves must be in good condition and must have good sealing performance,” he noted. “A barrier may look to be in good condition but not sealing. The mechanical properties of cement, for example, may be robust and provide coverage around the annulus, but it may not be sealing properly because of invisible micro-annuli or cracks that cause unwanted flow paths.” Additionally, cement, tubulars and other zonal isolation components experience degradation over time.   EmPulse multi-tube imaging, in its fourth generation, combines electromagnetic sensors with proprietary measurement and modeling techniques to measure the wall thickness of metal tubulars in well systems. “Wall thickness is an indicator of barrier condition and is used to quantify corrosion, which is progressive over time. Severe corrosion can lead to seal failures, leaks and unwanted flow paths, so routine surveillance is important,” Mr Feather said. In the Middle East, known for highly corrosive aquifers, the system has quantitatively recorded the individual tubular thickness of up to four concentric barriers. Pulse characterisation lab The acoustic-based spectral cement channel detection system records and analyzes the sound spectrum in the wellbore to detect the presence of fluid flow in otherwise undetectable micro-cracks or channels within annular cement that can result in leaks along the annulus after the well is put on production.   “From a production standpoint, this capability is important, particularly where one reservoir is communicating with another in a producing well,” he noted. “In water injection wells, the technique can confirm if the injected water is reaching the target reservoir or being diverted elsewhere.” Integrity failures resulting in sustained annulus pressure are often visible at the surface before problems escalate, so operators are embracing diagnostics as a proactive method for preventing zonal isolation issues, particularly in the Middle East, he said. “Historically, the industry has been reactive, but we believe there are significant benefits in conducting surveillance regularly and routinely to monitor the tube integrity and seal integrity of wells barriers.”

Diagnostics Behind the Barriers A wide range of tubulars are tested in the EmPulse characterization facility at TGT Oilfield Services’ technology center in Kazan, Russia, to ensure accurate metal wall thickness measurements. Wall thickness is an indicator of barrier condition.   A wide range of tubulars are tested in the EmPulse characterization facility at TGT Oilfield Services’ technology center in Kazan, Russia, to ensure accurate metal wall thickness measurements. Wall thickness is an indicator of barrier condition.   Alongside those efforts, companies are increasingly recognizing the value of using diagnostic systems to detect issues that compromise well barriers. “Because most well integrity problems occur in the outer periphery of the well, behind barriers such as tubulars and cement, a process for sensing and locating leaks, or flow paths along the annulus, is crucial,” said Ken Feather, Chief Marketing Officer, TGT Oilfield Services. The company provides “through-barrier” diagnostics using thermal, electromagnetic (EM) and acoustic energy.   The EmPulse multi-tube imaging system produces tube integrity diagnostics. Measurements performed from within the 3 1/2-in. production tubing show significant corrosion in the 13 3/8-in. casing, quantifying metal loss of 34% and 44% in the third barrier.   The EmPulse multi-tube imaging system produces tube integrity diagnostics. Measurements performed from within the 3 1/2-in. production tubing show significant corrosion in the 13 3/8-in. casing, quantifying metal loss of 34% and 44% in the third barrier.   “Barriers, such as tubulars, cement, elastomers, packers and valves must be in good condition and must have good sealing performance,” he noted. “A barrier may look to be in good condition but not sealing. The mechanical properties of cement, for example, may be robust and provide coverage around the annulus, but it may not be sealing properly because of invisible micro-annuli or cracks that cause unwanted flow paths.” Additionally, cement, tubulars and other zonal isolation components experience degradation over time.   EmPulse multi-tube imaging, in its fourth generation, combines electromagnetic sensors with proprietary measurement and modeling techniques to measure the wall thickness of metal tubulars in well systems. “Wall thickness is an indicator of barrier condition and is used to quantify corrosion, which is progressive over time. Severe corrosion can lead to seal failures, leaks and unwanted flow paths, so routine surveillance is important,” Mr Feather said. In the Middle East, known for highly corrosive aquifers, the system has quantitatively recorded the individual tubular thickness of up to four concentric barriers.   The acoustic-based spectral cement channel detection system records and analyzes the sound spectrum in the wellbore to detect the presence of fluid flow in otherwise undetectable micro-cracks or channels within annular cement that can result in leaks along the annulus after the well is put on production.   “From a production standpoint, this capability is important, particularly where one reservoir is communicating with another in a producing well,” he noted. “In water injection wells, the technique can confirm if the injected water is reaching the target reservoir or being diverted elsewhere.” Integrity failures resulting in sustained annulus pressure are often visible at the surface before problems escalate, so operators are embracing diagnostics as a proactive method for preventing zonal isolation issues, particularly in the Middle East, he said. “Historically, the industry has been reactive, but we believe there are significant benefits in conducting surveillance regularly and routinely to monitor the tube integrity and seal integrity of wells barriers.” Pulse characterisation lab