Innov Oil Issue 1 August 2012


Published on

InnovOil - Bringing you the latest innovations in exploration, production and refining

  • Be the first to comment

  • Be the first to like this

No Downloads
Total views
On SlideShare
From Embeds
Number of Embeds
Embeds 0
No embeds

No notes for slide

Innov Oil Issue 1 August 2012

  1. 1. ™ Published by vNewsBaseBringing you the latest innovations in exploration, production and refiningIssue One August 2012adrok’s atomicdielectricresonancescannerMapping deep surfacegeology with electromagnetic radiationPage 3deepwater Look! MEASURINGtesting No wires UPShawCor’s SSV predicts Red Spider’s Remote Eztek’s TallyBookpipeline performance Open Close Technology DAQ unitsPage 4 Page 8 Page 7
  2. 2. THEPOWERTOHANDLE THECOMPLEXITYOF RISKSwift and dramatic changes in business conditions, stricter regulations,intense public scrutiny: managing risk has never been more critical– and more complex.At DNV, we understand risk at all levels from the detailed technical to long-term business strategy, helping you to handle thecomplexity of risk.Classification • Verification • Technology qualification • Safety, health & environmental risk management • Asset risk management • Enterpriserisk management
  3. 3. August 2012 InnovOil by vNewsBase page 3A Stove, abeach and avirtual boreholeADROK’s ADR Scanner offers a new wayto examine the subsurface before drillingC onventional science says that electromagnetic like unconditioned electromagnetic waves, passes through most energy can only penetrate solid ground to a depth of materials (it has problems with dense metallic masses), and as it centimetres to a few metres (depending on wavelength). travels it causes the electrons it strikes to resonate in a characteristic So, in the 1980s, when carrying out experiments with manner. This resonance releases energy which is transmitted in partthe European Space Agency transmitting X band radar at a beach back to the surface detector. Here the resonant energy is analysedin Scotland (whose penetration was predicted to be in millimetres), and compared with a library of known patterns, to give a materialDr Colin Stove was surprised to find that he was imaging the water classification that resembles a Virtual Borehole Log, showingtable several metres below the surface of the beach. lithology and fluid content by depth. Depths are classified according Puzzled by this very unexpected effect, Dr Stove’s follow-up to a time base just as in a radar scan – the longer the return time ofresearch showed that because he was using a polarised transmission an “echo”, the deeper the a low power in a directional beam, the radiation he was In addition to its capability to detect materials and image withtransmitting was “trickling” into a standing wave, which acted like precision, the ADR Scanner has other advantages. The energyan electromagnetic drill, working its way past matter by making employed is very low (less than a watt), and the waves generatedthe atoms in its path resonate with rather than absorb the radiation. are non-destructive, so there is no detectible chemical or biologicalIn effect, the research was bearing out physics which had been change in the materials under investigation. ADR can operate atpredicted by Dr Feynmann’s revolutionary but still challenging close range or long-range, and can operate through air, and (so far)Quantum Electrodynamic (QED) theory, and as such was a real up to about 75 metres of water. ADR has now proven its ability tochallenge to traditional Maxwellian physics. classify strata at depth of up to 4,000 metres, and is working on extending this horizon. ADROK is currently working on makingADR ADR an airborne technology. The equipment itself is light,Research into QED and the dielectric effects of matter on energy compact and readily transportable, fitting into a handful of robustproduced a patent for the process, christened Atomic Dielectric cases weighing a total of 100 kgs. Power supply is a simple 12vResonance (ADR) in 1999, and since then the principles of ADR, battery. ADROK’s Virtual Borehole provides stratigraphy, rockusing focused polarised low energy radar waves, operated by characteristics, and finally actual rock petrography, all withoutADROK from its base in Edinburgh, UK, has been proved at drilling.ever deeper depths and ADROK has developed a classification ADROK has worked with operators to test ADR on more thanlibrary that allows it to identify the chemical composition of target 20 operating onshore oilfields and gas fields. During these, it wasstructures down to 4,000 metres. demonstrated that ADR could successfully detect and image oil Where a Virtual Borehole generates data which does not fit and gas deposits at depths from 300 metres to 4 km. In one case inexisting ADROK library patterns, it is necessary to benchmark a North Africa, ADROK’s ADR Scanner was tested against a previoussurvey against a known well log, but even here, a Virtual Borehole drilling log and independently located a thin subsurface gas layercan remove the need to drill multiple wells on a structure to to within 7 metres depth range. BG Group, Teck Resources andcharacterise it. ADROK’s experience is that it can help cut the cost Caithness Petroleum are among some of Adrok’s repeat customers.of characterising an onshore structure by 90% in an average case. One answer ADR Scanning can not yet give is whether a rock In 2007 ADROK detected a gas filled rock formation at formation is porous or permeable. This will be the subject of future750 meters for Caithness Petroleum (corroborated by subsequent trials. Also under trial is the ability to scan through greater waterdrilling). Since then, with substantial investment from Teck, depths, and ADROK is currently looking for opportunities to deployADROK has been developing and improving its technology to help the ADR Scanner in deeper water surveys to reach this objective. nthe hydrocarbon industry cut costs. ADROK’s technology centres on the ADR Scanner. The ADR Contact:Scanner conditions and transmits ultra-wide bands of collimated Gordon Stove, Managing Director, Adrok Ltdradio-wave, micro-wave, sub-micro-wave and thermal infra-red EM Email: ; Telephone: 0131 555 6662 energy. The transmitted energy, rather than being rapidly absorbed Website:
  4. 4. page 4 InnovOil by vNewsBase August 2012Testsin thepipelineShawCor’s SSV offers a means ofpredicting pipeline performance,which will be critical as operationsmove into deeper and deeper watersA s the world’s production frontier moves into ever-deeper water, the problem of predicting how subsea production systems will perform over time and under pressure comes very much to the fore. A key factor is thermalinsulation – working under great pressure, in an ambient temperaturenear freezing, how well will pipe, valves and other subseaproduction structures maintain their internal fluid temperatures? Ifproduction has to be stopped for any reason, how long have you gotbefore the internal temperature of your system falls below a criticalpoint? Until now, theoretical models, limited experience elsewhere,a large element of over-specification and a pinch of good luckhave been the only way to specify pipe and valves for deepwatercompletions. That obviously is not good enough for the long term, so ShawCorhas built the world’s largest and most capable vessel for simulatingoffshore service conditions up 3,000 metres water depth (300 bar)and with fluid temperatures up to 180°C – the Shawcor SimulatedService Vessel (SSV) The SSV is an 82 tonne pressure vessel located in the ShawCorSubsea Test Facility in Toronto, Canada, in which the sample beingtested is loaded on to a carriage and then inserted into a pressurecylinder. The test sample, which can be rigid or flexible pipe, Once thermal equilibrium is established, the SSV is pressurised andvalves, seals, joints, flanges, and even custom fabricated parts, is held at the required pressure for the duration of the test. Pressure isthen heated to the desired test temperature, while being subjected to increased in steps to assess the immediate and long-term responseexternal pressure to simulate its planned operating environment. The of the insulation properties to changes in pressure at a specificSSV can test multi-layer or injection-moulded insulation coating operating temperature, and so capture the reaction of the systemsystems, and can take pipe up to an external diameter (including to pressure changes. For example, the typical response for foam isinsulation) of 910 mm. that it compresses over time, while for a solid polymer, the material The data collected from a complex suite of sensors gives hard shows an immediate response that plateaus after about one week.foundations to computer models of how the pipe element willperform over time. Key tests are done to determine how well To create consistent and reliable data the mea­ urement and sits thermal insulation performs, and to find the rate and effect control system of the SSV has several features. The test sampleof compressive creep as external pressure deforms the thermal is heated with a seven-zone electrical heater and controlled byinsulation and thus changes the rate of heat loss. The SSV can also thermocouples in each zone.measure the performance of new materials and thermal insulationdesigns. The following parameters are monitored: The sample to be tested is instrumented with thermal sensors • Water temperatureand heat flux sensors to determine the heat loss from the system. • Pressure
  5. 5. August 2012 InnovOil by vNewsBase page 5• Temperature of the insulation coating surface Further tests such as triaxial creep and finite element analysis• Heat flux in the radial direction at different zones (FEA) modelling of the insulation can run in parallel with the SSV• Radial displacement, using linear variable differential tests to establish reliable predictors of the long-term performance of transformer (LVDT) sensors the insulation to minimise project risk.• Power consumption in each zone. The SSV has already successfully completed several tests for future offshore pipelines to be installed in the Gulf of Mexico and Heat flow is measured directly by sensors mounted on the test Brazil. The advanced testing facility has also been awarded the 2012pipe to provide real-time accurate measurements along the length of Spotlight on New Technology Award by the Offshore Technologythe pipe. The heating system provides precise temperature control Conference (OTC), the world’s foremost event for the developmentwith a high capacity chiller and circulating pump, to maintain a of offshore resources in the fields of drilling, exploration, productionwater temperature of 4-6°C. The system continuously monitors and and environmental protection. nrecords thermal properties during the test. The SSV’s precise measurement capabilities allow detailed Contact:characterisation of performance and accurate real-time measurement Vlad Popovici, Marketing Managerof heat flux, thermal conductivity and U-value (the rate of heat loss), ShawCor Ltd.all of which can then be used to model and design the insulation Tel: +1 416 744 5839system.
  6. 6. page 6 InnovOil by vNewsBase August 2012 When your pipeline is 3,000 meters subsea, you can’t afford uncertainty ShawCor’s new Simulated Service Vessel (SSV), winner of the 2012 OTC Spotlight on New Technology Award, is the industry’s largest and most advanced deepwater test chamber for end-to-end thermal insulation systems. It accommodates pipe samples up to 6 m long and 910 mm external diameter, and simulates water depths to 3,000 m and temperatures up to 180°C. The innovative SSV helps validate 2012 Award Winner Watch the SSV video: your subsea insulation design through accurate determination of U-value, cool-down and compressive creep; precise control of testing process; real-time data acquisition and expert analysis. ShawCor – when you need to be sure
  7. 7. August 2012 InnovOil by vNewsBase page 7Eztek measures up“If you can’t measure it, how can you manage it?”W ith a number of its clients in the oil industry posing this question, Eztek embarked on the development of the TallyBook range of data acquisition (DAQ) technology. TallyBook isa standalone DAQ unit designed for use by the oil and gasindustry in harsh environment and hazardous areas. TallyBook DAQ units have the capacity to providetransparent reporting on complex procedures such aswell interventions, with a view to making operationssafer and more efficient. Another key feature ofthe technology is that it offers post-operationalanalysis so that future processes can beoptimised.North Sea case studyTallyBook technology is currently beingused in a major project in the North Sea inwhich a leading operator is working on aseries of long-standing wells. The operatoris performing a number of chemical squeezeprocedures to regain production levels by cleaningup the well, and requires pinpoint data acquisition toensure the safety and efficiency of the work. The key parameters the operator wished to measure andrecord in the project were temperature, flow and density.Eztek developed the Zone 1 certified TallyBook to meet theclient’s criteria, as well as that of the EU’s ATEX directive onequipment that can operate in explosive atmospheres. The Zone 1 TallyBook was subsequently mounted on thepumping skid and attached to the required sensors. It becameapparent very quickly that the information delivered by the unit wasinvaluable on many levels. It not only allowed the water-chemical However, the addition of a 10.4-inch (264-mm) touch screen makesmix to be read in real time, but could also be adjusted, thus giving it versatile and simple to use as the operator can swiftly switch fromthe best possible results immediately. graphical to digital display. Furthermore, Eztek’s application offered the operator the ability Applications for this unit range from coil-tubing operationsto download the data that was acquired for analysis. This is an for measuring pipe heavy/pipe light to depth and pressure. Theespecially advantageous feature for operators working in hazardous TallyBook Touch is also adaptable to pumping equipment thatareas as it stores the data to be examined and can be retained as a allows for a Zone 2 unit to be employed.history of the well. Eztek promises its clients a dedicated after-sales support experience, with the company’s in house software development teamEfficiency on hand to deal with any permutations thrown up by the TallyBookThe most obvious benefit offered by the TallyBook DAQ units is units during operations in the field. Most software updates canthe time saving efficiencies that they offer. Previously, a chemical be done via email and sent to anywhere in the world. This makessqueeze procedure on an old well would have to be carried out every the TallyBook an essential piece of kit for operators working insix months. But with the application of Eztek’s technology, the hazardous environments across the globe that are looking to cutexpected time until the next intervention could be up to 15 months. costs and save time. The TallyBook also offers project-planning benefits. Using the Eztek also produces a wide range of safety and efficiencytechnology, it is now easier for operators to gauge the amount of enhancing products from intercom and video systems to wirelinechemicals needed for each process, thus reducing the need for panels. nunnecessary stock with lower logistical costs offshore. Contact:In Touch Mervyn Newberry, Business Development ManagerThe latest addition to Eztek’s range of measurement and control is the TallyBook Touch. The unit is a Zone 2-rated Tel: +44 (0)1224 798829 Mobile: +44(0)780 242 9975DAQ system with the same recording features as its siblings.
  8. 8. page 8 InnovOil by vNewsBase August 2012Look! No wiresRed Spider has developed innovative remote-controlled technology foroil companies to tackle challenging intervention and completion workR ed Spider has developed a range of new technology well completions and workovers via the removal of wireline runs. for operators in the oil industry to tackle challenging This in turn makes the operation more efficient and safer. intervention and completion work with a view to In order to provide solutions to those problems, the 70-strong mitigating risks and cutting costs. Aberdeen-based company has invested heavily in R&D with The UK-based company’s flagship innovation, eRED®, is a backing from the oil and gas Industry Technology Facilitator (ITF).downhole computer-controlled valve that can be opened and closed This investment, allied with close interaction with operators andmultiple times by remote control without the need for intervention. industry bodies, has enabled it to develop its suite of open-closeThe tool has been designed as part of Red Spider’s Remote Open technology tools that are designed to deal with the particularClose Technology product line, which aims to save time and money challenges thrown up by completion and intervention work.whilst simultaneously removing risk during operations. The company’s breakthrough eRED valve has now been used in excess of 100 times in the field by over 20 oil companies. OperatorsSolutions that have used the technology have reported savings of more thanThe Remote Open Close Technology product line consists of US$500,000 during a single subsea completion operation, typicallyeRED, eRED-FB (a tubing-mounted, full bore version of eRED) reducing slickline runs from eight to one. In deepwater workoverand PowerBall® (a formation isolation valve). Each tool has an operations, savings of up to 36 hours and US$800,000 have beenintegrated power supply and electronic control module so it can recorded in a single job.carry out pre-programmed instructions either autonomously or by eRED is normally pre-installed or deployed below a carrier suchreacting to a command from surface. as a wireline lock. In practice, it works exactly like a wireline plug The driving force behind Red Spider’s intervention-less technology but without requiring any intervention to deploy or retrieve it when ais a need within the industry to cut rig times and costs by simplifying barrier needs to be put in place or removed. You hit home runs, not by chance but by preparation Jim Rohn eRED in a league of its own ® 100 runs and counting Our eRED valve reduces wireline runs - saves time, saves money and removes risk from well operations.
  9. 9. August 2012 InnovOil by vNewsBase page 9Contact:Red Spider Technology Tubing HangerPeregrine Road, Westhill, Aberdeenshire, AB32 6JLTel: +44 1224 275000 Standard Lock 4.875 in Any application where a wireline lock and plug are used can bereplaced by an eRED valve, thus achieving exactly the same resultswithout the need for repeated intervention jobs. This removes the eREDrisk and cost associated with multiple slickline runs. An eRED action, such as opening or closing, is initiated onlywhen a specific well condition (known as a trigger) is detected.Upon successful completion of that action, the eRED can look foranother trigger, which in turn initiates the next action. Using a seriesof different trigger and action combinations, the eRED can be usedin complex well programmes, opening and closing as many times asrequired without any intervention. The next product in Red Spider’s Remote Open CloseTechnology line is the eRED-FB, which is the tubing-mounted Tubingversion of the eRED. It consists of a remotely actuated full-bore ballvalve that can be opened and closed multiple times, controlling flowthrough the tubing without the need for any umbilical control line. The use of eRED-FB completely eliminates the requirementfor any wireline runs during a completion placement operation,resulting in savings of between 32-38 hours and US$600,000 toover US$800,000 in subsea operations. Moreover, a mechanicaldownhole barrier is present at all times during operations, to be Production Packeractivated upon request and to take control of the well. Eliminating the requirement to deploy traditional control line-operated equipment speeds up the completion process, bringing wellson stream sooner and reducing the risk of exposure to bad weather. When closed, the eRED-FB provides a bi-directional downholebarrier, capable of holding up to 5,000 psi from above or below.When open, the large internal diameter maximises production orinjection and allows easy access to the well and equipment belowthe valve. Another Red Spider innovation, PowerBall, is a reservoirisolation barrier designed for reliability in debris-laden environments.It is intended to be run open, then subsequently closed during lowercompletion deployment and finally to be re-opened permanently byremote command for production or injection to commence. Remote opening of PowerBall happens with no pressure cycles, buton detecting a specific trigger, much in the same way as with eRED. Standard Lock 4.313 inThis in turn results in a much more flexible and efficient operation. Savings of up to 12 hours can be achieved thanks to the efficientactivation method of PowerBall. All the moving parts are placedbelow the closed ball, where they are not exposed to debris,improving the reliability of the tool. Drilling technologies that are exposed to large amounts of eREDdebris can result in operational failure and costly shutdown time.By moving the mechanical parts of the ball mechanism below theclosed ball area of the tool, and as a result protecting them fromdebris, PowerBall offers maximum reliability in dirty environments.Avoiding remedial action caused by failure of a fluid loss device canresult in savings in the region of US$2 million. Tubing eRED and its sister applications are particularly suited fordeepwater and subsea work, where rig-time savings are mostvaluable. This makes the products especially suitable for deploymentin the North Sea, Brazil, Gulf of Mexico, West Africa, Australia andAsia-Pacific, where deepwater oil exploration is ramping up rapidly. n
  10. 10. page 10 InnovOil by vNewsBase August 2012Reaching deeperfor reservoirknowledgeSenergy’s IP package provides operators with a chanceto move into a new age of reservoir predictionS energy, a global provider of energy consulting services, has led the way in reservoir modelling for many years incorporating its Interactive Petrophysics package (IP™), and has now released a significant update of IP™ withmuch enhanced visualisation and interpretation tools aimed at givingthe reservoir operator increasing ability to characterise reservoirs,whether new or mature. Until now, reservoir modellers would have sourced image loganalysis or sedimentology services from a third party, and thenhad to cobble together a reservoir model by bolting these separatecomponents together into a statistical illustration of how a reservoirmight be expected to behave. The new release of IP™ enablesenhancement of the model from illustration to prediction. depth,” to predict the sand-free operating envelope for a range of IP™ contains an Image Log Processing and Analysis module, rock strengths and well completion options.which fully covers the workflow from raw data processing, speed IP™ is now also equipped with a variety of workflowscorrection, image enhancements, thorough manual and automatic for organic shale reservoirs, plus general speed and memorypicking, through to statistical analysis of the results, including improvements.stereonet analysis. High resolution pseudo images of the borehole Senergy provides static and dynamic reservoir evaluation andwall are produced from petrophysical measurements that allow solutions which can cover the complete cycle for a reservoir fromgeological and drilling related features in the borehole to be exploration through appraisal and development to ‘brown field’identified, interpreted and, importantly, oriented. This data helps a greatly improved static reservoir model, and so gives The Aberdeen-headquartered company, with over 550 staffreservoir engineers a better understanding of a reservoir’s dynamics located around the world, is continuing to expand its globaland viability, maximising returns. footprint, and can point to a proven track record in this field. Also new is the NavQC module to correct bad navigation data, Multi-disciplinary teams are often mobilised to undertake specificDual OBMI support and an interactive, high resolution 3D engine geological projects for the client. Recent examples include anfor visualisation of Image Logs. integrated project in the Neuquen basin, Argentina, where Senergy Another new component for IP™ is nDPredictor, which has been technical staff were involved in optimising facilities from thedesigned to address highly nonlinear geological data and is based on reservoir to the separation facilities and in a number of mature Northa Geological Differential Method (GDM). This integrates various Sea fields where integrated Senergy technical teams worked withforms of data, preserving geological identity, to produce a true point operators to optimise infill locations and point solution of the selected target parameters. nDPredictor Senergy’s view is that rather than going to several differentproduces a deterministic solution in comparison to the statistical companies that specialise in one or two things, it offers the wholemethods which can only produce a realisation. package under one roof. n A further win for IP™ is the picture it gives Geomechanics andProduction engineers of the likelihood of rock failure in sandstone Contact:reservoirs and hence the chance of sand production in the well. Senergy,Calculations can be run for an open hole or a cased and perforated 15/16 Bon Accord Crescent, Aberdeen AB11 6DE, UKcompletion, and for any well azimuth and deviation. IP™ can Tel: +44 1224 213440analyse multi-depth situations, allowing the user to predict the onset email: sand failure across the whole reservoir, or it can be set to “discrete web:
  11. 11. ENHANCING PERFORMANCE • •ame: SURVITECneg_PMS.eps Colourway: 100% Pantone PMS 158c 100% Opaque White IN THE MOST EXTREME CIRCUMSTANCES • Providing total logistics support for the past 35 years • Operating a rental fleet of 28,000 suits • Providing equipment for oever 40,000 helicopter flights per annum worldwide • Travelling to 550 offshore destinations Survitec Group Survitec House, Kirkton Drive, Dyce, Aberdeen, AB21 0BG, United Kingdom Tel: +44 (0)1224 214460 / Email:
  12. 12. page 12 InnovOil by vNewsBase August 2012No inhibitionsOptimising hydrate inhibitorinjection with HydraCHEKS ome 80 years ago oil producers trying to transport natural unpleasant consequences for the Capex costs of installing plant to gas in cold climates made an uncomfortable discovery. handle the inhibitors, and Opex costs for it to the point of origin, When natural gas and water come together at low injecting it and ultimately recovering or disposing of it. temperatures water molecules rearrange to form a ball-like Hydrafact, a spin-out company from the world-class hydrocarboncage around a gas molecule, producing gas hydrates. Hydrates are research campus of Heriot-Watt University in Scotland, hassolid, and relatively stable, so form large immobile plugs inside worked with BP, Total, Chevron, Statoil and Petronas to developpipelines. Apart from obstructing the gas flow, operators found a technology to cut these costs, without compromising eitherthat clearing the blockage by heating created serious risks of a operational safety or performance.catastrophic release of gas in a runaway PVT event. The result is HydraCHEK, an analytical tool to give producers A problem that was occasional, even exotic, in the 1930s, is fast and accurate measurements of the hydrate inhibitor, and saltnow commonplace. Deepwater wells and export pipelines work concentrations from produced water samples. This data whenin an ambient temperature of near zero, even in warm climates. combined with the hydrocarbon fluid composition is used to findShallower plant also finds itself near freezing in winter, and of the actual phase boundary for the system being tested.course onshore gas is being produced in locations where zero Using acoustic velocity and electrical conductivity tests onwould be a balmy summer’s day. downstream produced water samples, an Artificial Apart from complete water removal (difficult!), Neural Network, and a proprietary thermodynamicthe generally accepted solution is to add model, HydraCHEK correlates results tochemicals that act as hydrate inhibitors to produce accurate predictions for thechange the conditions at which hydrates hydrate phase boundary of a system.can form. The most commonly used Combined with the operating pipelineinhibitors are methanol and ethylene temperature and pressure the actualglycol (MEG), which act to reduce the degree of inhibition and safety margin fortemperatures at which hydrates are a system can be easily determined. All ofstable. Other solutions are to use Kinetic this is done by a robust field-capable unit,Hydrate Inhibitors (KHIs) which within 10 seconds of measurement.extend the time it takes for hydrates to The result? With a much moreform, or Anti-Agglomerants (AAs), representative picture of the hydrate riskwhich don’t stop hydrates forming, and inhibitor effect, the pipeline operatorbut limit their size and prevent is now able to optimise the amountclustering and deposition long of inhibitor, and to understand muchenough for the system to enter a more clearly what their safety marginswarmer environment. are (obviously, the size of the safety The bad news, of course, is that margin is the choice of the pipelinethese additives are not free, and operator, and HydraCHEK gives themust be transported, stored and operator better knowledge to makepumped to the point of origin of the that choice).gas flow for injection, making their In practice, using HydraCHEKuse even more expensive. Given that very quickly results in greatly reducednatural gas is already a relatively low value material, the economics inhibitor use. In a recent application on a platform in the North Sea,of hydrate prevention is a major concern to a gas producer, and can the operator proved that existing inhibitor levels were well aboveeven turn a good field into a bad one. In extreme cases, the inhibitor those actually required – in short, the system was being hugely overrequirements may be greater than 50% by weight of the produced inhibited. Utilizing HydraCHEK the operator was able to roughlywater in a gas pipeline. halve their inhibitor injection, with no loss of safety, and a NPV of In current practice, the amount of hydrate inhibitor needed to savings calculated at above £10m (US$15.7m).protect a system is calculated based on the hydrate phase boundary HydraCHEK is currently being deployed by Total,for the specific fluid composition (of gas, oil, water and salt) being ConocoPhillips and Dolphin Energy. ntransported and the predicted worst case temperature and pressureoperating conditions. Other factors must also be considered, Contact:such as the loss of some of the inhibitor, owing to its own phase Tom Gorlach,changes from liquid to gas. To counter the uncertainties for a given Hydrafact Ltd.system, a large safety margin is normally applied to minimise the email: tom.gorlach@hydrafact.comrisk of hydrate blockage, with the net result being that presently Tel: +44 131 449 7472the industry is using far more inhibitor than it needs to. This has Web:
  13. 13. August 2012 InnovOil by vNewsBase page 13Thinkingahead withe-plannerUK firm e-products is designing a suite of softwaresolutions for use throughout the oil and gas industryE dinburgh-based e-products, a business solutions can also be employed independently. The costing module allows developer, is in the final stages of developing a suite of companies to estimate and tender for projects easily, enabling software solutions for use across the oil and gas industry. managers to keep on top of projects via comprehensive dashboards The firm was commissioned by engineering and reports. A fully audited variations system also allows for mid-consultancy Optimus to design e-planner, which is being used to project budgetary changes.manage and control all of the latter’s 193 current projects. Scheduling is synchronised with Oracle’s Primavera P6 Various modules make up the fully integrated e-planner system, Enterprise Project Portfolio Management, and for companies thatwith e-products currently at work developing the final phase of the do not use Oracle, e-planner has an inbuilt scheduling module.system – invoicing. Once this has been launched in early September, E-planner can be configured to send automatic reminder emails tothe company intends to release the software to other companies trigger data entry (for example timesheet entry). Moreover, projectsearching for efficient project planning tools. managers are able to vet times if required. These features can help The e-planner system provides oil and gas companies with a remove bottlenecks while reducing billing errors.comprehensive tool to manage projects from initial estimate phase The absence module allows managers to track absences – suchthrough to completion, helping them to come in on time and budget. as planned contractor absences and staff holiday entitlements – on E-planner relies on its integrated nature to save time and avoid a companywide basis, allowing for greater planning of projecterror, while saving users from having to switch manually between resources. A Microsoft Outlook add-in allows central filing ofseveral separate systems. E-planner not only reduces administration important project emails, which can then be accessed by the entireoverheads but also provides greater visibility throughout a project’s team. The contracts module ensures that renewal dates are neverlifecycle. missed, by sending notifications of any contracts that require E-planner was conceived two years ago and commissioned by attention. Contract documents are also securely stored so they canAberdeen consultancy Optimus, which provides process, facilities be easily referenced. The invoicing module reduces errors, identifiesand safety engineering, and project execution. Optimus had bottlenecks and increases cash flow by automatically generatingsearched for a single system to manage all of its projects while invoices from project data. ntightening up project controls – and having failed to find such aplatform commissioned e-products to build one. In 2011 Optimus Contact:reported record sales of over £10m (US$15.7m), and pre-tax Trevor Cattleprofits of £900,000 (US$ 1.4m), using e-planner as its core project email: software. Tel: 0845 009 4050 E-planner is a fully integrated system, whose various modules web:
  14. 14. Oil SpillDetection &MonitoringHydrocarbon Oil SensorsProven range of in-situ sensors optimisedfor monitoring crude and refined oil fromcoastal margins to deep ocean. Delivering Now Configurable fluorimeters Targeted spectral response Oil spill monitoring Pipeline leak detection Environmental remediation Long term monitoringChelsea Technologies Group Ltd+44 (0)20 8481
  15. 15. August 2012 InnovOil by vNewsBase page 15Casting acritical light    The general assembly of AQUAMeasuring is shown in Figure tough conditions III hydrocarbons in 1. Thecan be ainstrument comprises four major sub difficult job but Chelsea Technologies’ assemblies:fluorometers are up to the taskU a) A Turret Assembly that houses  K-based Chelsea Technologies Group’s range of the optical components and in situ fluorometers have been used in the offshore industry since 1990. Originallycap makes the front developed for for military applications, the UV AquaTracka has the ability to the Pressure Housing.detect very low levels of hydrocarbons to depths of 6,000 metres. b) UviLux Electronics shallower depths (600The newly launched An is designed for Chassis that contains:metres) but now yields equivalent sensitivity performance. Bothinstruments are capable ofthe signal and refined oils in the  detecting crude circuits of themarine and freshwaterinstrument.and are in use around the globe. environment “There has been unprecedented demand for our hydrocarbon detection sensors following thelight source Gulf ofits power  the oil spill in the and Mexico,” supply.Bruce Kimber, Chelsea’s customer services manager, told InnovOil. c) A Pressure Housing thatHe went on to say that: “More recently we’ve been contacted tosupply the UviLux hydrocarbon sensor to monitor potential spillage encloses the Electronics Chassis.during the procedure of offloading the ship’s fuel from the stricken Costa Concordia vessel inRear End Cap that is used to d) A Italy.”  Monitoring authorities tend toPressure Housing. seal the select the UV AquaTracka becauseof the robust measurements offered by the fluorometer, as well as itsunparallel sensitivity and full ocean depth capability. The turret has two plain bores Recent work within Chelsea’s R&D department has nowyielded equivalent sensitivityinto it, one from the UviLux in- machined performance bore houses thesitu fluorometer. This UV LED optics, the other lighter excitation fluorometer is smaller and the than the 6,000m rated UV AquaTracka. The UviLux provides a emission optics. The optical  depth rating of 600 metres and offers a high specification in-situ hydrocarbon sensor at lower cost.consist of can be configured components The UviLux a series offor measurements of crude oil,filters and, on the detection lenses and refined oils or CDOM for otherapplications. n side only, a photodiode. Each boreContact: runs parallel with the length of the Ellen Keegan, instrument and is optically linked by a Chelsea Technologies Group prism mounted separately in the topTel: +44 (0)20 8481 9019. section of the turret. The lenses, filters and photodiode are held in their correct axial positions by a set of spacers. The optical layout is shown in Figure 2.   AQUAtracka III (left) and its new sibling, UviLux  AQUAtracka III assembly 
  16. 16. Published by vNewsBas ™ e Bringing you the latest innov ations in exploration, producti Pilot issue on and refining July 2012 adrok’s atomic dielectric resonance scanner Mapping deep surface geology with electro magnetic radiation Page 3 deepwater look! testing HigHer no wires sensitivity ShawCor’s SSV predicts Red Spider’s Remote pipeline performance Chelsea Technologies’ Open Close Technology Page 4 fluorometers deliver Page 7 Page 14 InnovOil™ is the new monthly from NewsBase If you would like to receive a FREE copy of InnovOil or advertise with us please contact our media sales manager on the details below.Allan Miller NewsBase Limited Centrum HouseMedia Sales Manager Tel: +44 (0)131 550 9294 108-114 Dundas Streetemail: web: Edinburgh EH3 5DQ