adrok’s atomic dielectric resonance scannerMapping deep surface geology with electro magnetic radiationPage 3

look! no wiresRed Spider’s Remote Open Close Technology Page 8

measUrinG UPEztek’s TallyBook DAQ units Page 7

deePwater testinGShawCor’s SSV predicts pipeline performance Page 4

Published by vNewsBase

Issue One August 2012

Bringing you the latest innovations in exploration, production and refining

™

Swift and dramatic changes in business conditions, stricter regulations, intense public scrutiny: managing risk has never been more critical – and more complex.

HANDLE THE COMPLEXITYOF RISK

THEPOWERTO

At DNV, we understand risk at all levels from the detailed technical to long-term business strategy, helping you to handle the complexity of risk.

Classification • Verification • Technology qualification • Safety, health & environmental risk management • Asset risk management • Enterprise risk management

www.dnv.com/energy

InnovOil by vNewsBaseAugust 2012 page 3

ADROK’s ADR Scanner offers a new way to examine the subsurface before drilling

COnventiOnAl science says that electromagnetic energy can only penetrate solid ground to a depth of centimetres to a few metres (depending on wavelength). So, in the 1980s, when carrying out experiments with

the european Space Agency transmitting X band radar at a beach in Scotland (whose penetration was predicted to be in millimetres), Dr Colin Stove was surprised to find that he was imaging the water table several metres below the surface of the beach.

Puzzled by this very unexpected effect, Dr Stove’s follow-up research showed that because he was using a polarised transmission at a low power in a directional beam, the radiation he was transmitting was “trickling” into a standing wave, which acted like an electromagnetic drill, working its way past matter by making the atoms in its path resonate with rather than absorb the radiation. in effect, the research was bearing out physics which had been predicted by Dr Feynmann’s revolutionary but still challenging Quantum electrodynamic (QeD) theory, and as such was a real challenge to traditional Maxwellian physics.

ADRResearch into QeD and the dielectric effects of matter on energy produced a patent for the process, christened Atomic Dielectric Resonance (ADR) in 1999, and since then the principles of ADR, using focused polarised low energy radar waves, operated by ADROK from its base in edinburgh, UK, has been proved at ever deeper depths and ADROK has developed a classification library that allows it to identify the chemical composition of target structures down to 4,000 metres.

Where a Virtual Borehole generates data which does not fit existing ADROK library patterns, it is necessary to benchmark a survey against a known well log, but even here, a virtual Borehole can remove the need to drill multiple wells on a structure to characterise it. ADROK’s experience is that it can help cut the cost of characterising an onshore structure by 90% in an average case.

In 2007 ADROK detected a gas filled rock formation at 750 meters for Caithness Petroleum (corroborated by subsequent drilling). Since then, with substantial investment from teck, ADROK has been developing and improving its technology to help the hydrocarbon industry cut costs.

ADROK’s technology centres on the ADR Scanner. the ADR Scanner conditions and transmits ultra-wide bands of collimated radio-wave, micro-wave, sub-micro-wave and thermal infra-red eM energy. the transmitted energy, rather than being rapidly absorbed

a stove, a beach and a virtual borehole

like unconditioned electromagnetic waves, passes through most materials (it has problems with dense metallic masses), and as it travels it causes the electrons it strikes to resonate in a characteristic manner. this resonance releases energy which is transmitted in part back to the surface detector. Here the resonant energy is analysed and compared with a library of known patterns, to give a material classification that resembles a Virtual Borehole Log, showing lithology and fluid content by depth. Depths are classified according to a time base just as in a radar scan – the longer the return time of an “echo”, the deeper the target.

in addition to its capability to detect materials and image with precision, the ADR Scanner has other advantages. the energy employed is very low (less than a watt), and the waves generated are non-destructive, so there is no detectible chemical or biological change in the materials under investigation. ADR can operate at close range or long-range, and can operate through air, and (so far) up to about 75 metres of water. ADR has now proven its ability to classify strata at depth of up to 4,000 metres, and is working on extending this horizon. ADROK is currently working on making ADR an airborne technology. the equipment itself is light, compact and readily transportable, fitting into a handful of robust cases weighing a total of 100 kgs. Power supply is a simple 12v battery. ADROK’s virtual Borehole provides stratigraphy, rock characteristics, and finally actual rock petrography, all without drilling.

ADROK has worked with operators to test ADR on more than 20 operating onshore oilfields and gas fields. During these, it was demonstrated that ADR could successfully detect and image oil and gas deposits at depths from 300 metres to 4 km. in one case in north Africa, ADROK’s ADR Scanner was tested against a previous drilling log and independently located a thin subsurface gas layer to within 7 metres depth range. BG Group, teck Resources and Caithness Petroleum are among some of Adrok’s repeat customers.

One answer ADR Scanning can not yet give is whether a rock formation is porous or permeable. this will be the subject of future trials. Also under trial is the ability to scan through greater water depths, and ADROK is currently looking for opportunities to deploy the ADR Scanner in deeper water surveys to reach this objective. n

Contact: Gordon Stove, Managing Director, Adrok LtdEmail: gstove@adrokgroup.com ; Telephone: 0131 555 6662 Website: www.adrokgroup.com

InnovOil by vNewsBase August 2012page 4

ShawCor’s SSv offers a means of predicting pipeline performance, which will be critical as operations move into deeper and deeper waters

AS 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 thermal

insulation – working under great pressure, in an ambient temperature near freezing, how well will pipe, valves and other subsea production structures maintain their internal fluid temperatures? If production has to be stopped for any reason, how long have you got before the internal temperature of your system falls below a critical point? Until now, theoretical models, limited experience elsewhere, a large element of over-specification and a pinch of good luck have been the only way to specify pipe and valves for deepwater completions.

that obviously is not good enough for the long term, so ShawCor has built the world’s largest and most capable vessel for simulating offshore service conditions up 3,000 metres water depth (300 bar) and with fluid temperatures up to 180°C – the Shawcor Simulated Service vessel (SSv)

the SSv is an 82 tonne pressure vessel located in the ShawCor Subsea test Facility in toronto, Canada, in which the sample being tested is loaded on to a carriage and then inserted into a pressure cylinder. The test sample, which can be rigid or flexible pipe, valves, seals, joints, flanges, and even custom fabricated parts, is then heated to the desired test temperature, while being subjected to external pressure to simulate its planned operating environment. the SSv can test multi-layer or injection-moulded insulation coating systems, and can take pipe up to an external diameter (including insulation) of 910 mm.

the data collected from a complex suite of sensors gives hard foundations to computer models of how the pipe element will perform over time. Key tests are done to determine how well its thermal insulation performs, and to find the rate and effect of compressive creep as external pressure deforms the thermal insulation and thus changes the rate of heat loss. the SSv can also measure the performance of new materials and thermal insulation designs.

the sample to be tested is instrumented with thermal sensors and heat flux sensors to determine the heat loss from the system.

tests in the pipeline

Once thermal equilibrium is established, the SSv is pressurised and held at the required pressure for the duration of the test. Pressure is increased in steps to assess the immediate and long-term response of the insulation properties to changes in pressure at a specific operating temperature, and so capture the reaction of the system to pressure changes. For example, the typical response for foam is that it compresses over time, while for a solid polymer, the material shows an immediate response that plateaus after about one week.

to create consistent and reliable data the mea surement and

control system of the SSv has several features. the test sample is heated with a seven-zone electrical heater and controlled by thermocouples in each zone.

The following parameters are monitored:• Water temperature• Pressure

InnovOil by vNewsBaseAugust 2012 page 5

• Temperature of the insulation coating surface • Heat flux in the radial direction at different zones • Radial displacement, using linear variable differential

transformer (LVDT) sensors• Power consumption in each zone.

Heat flow is measured directly by sensors mounted on the test pipe to provide real-time accurate measurements along the length of the pipe. the heating system provides precise temperature control with a high capacity chiller and circulating pump, to maintain a water temperature of 4-6°C. The system continuously monitors and records thermal properties during the test.

the SSv’s precise measurement capabilities allow detailed characterisation of performance and accurate real-time measurement of heat flux, thermal conductivity and U-value (the rate of heat loss), all of which can then be used to model and design the insulation system.

Further tests such as triaxial creep and finite element analysis (FeA) modelling of the insulation can run in parallel with the SSv tests to establish reliable predictors of the long-term performance of the insulation to minimise project risk.

the SSv has already successfully completed several tests for future offshore pipelines to be installed in the Gulf of Mexico and Brazil. the advanced testing facility has also been awarded the 2012 Spotlight on new technology Award by the Offshore technology Conference (OtC), the world’s foremost event for the development of offshore resources in the fields of drilling, exploration, production and environmental protection. n

Contact:Vlad Popovici, Marketing ManagerShawCor Ltd.Tel: +1 416 744 5839vpopovici@shawcor.com

InnovOil by vNewsBase August 2012page 6

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 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

When your pipeline is 3,000 meters subsea, you can’t afford uncertainty

Watch the SSV video:www.shawcor.com/ssv

2012 Award Winner

shawcor.com

SC_SSV_TBS_Innovoil_070312.indd 1 12-07-03 3:27 PM

InnovOil by vNewsBaseAugust 2012 page 7

“If you can’t measure it, how can you manage it?”

WitH 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 is

a standalone DAQ unit designed for use by the oil and gas industry in harsh environment and hazardous areas.

tallyBook DAQ units have the capacity to provide transparent reporting on complex procedures such as well interventions, with a view to making operations safer and more efficient. Another key feature of the technology is that it offers post-operational analysis so that future processes can be optimised.

North Sea case studytallyBook technology is currently being used in a major project in the north Sea in which a leading operator is working on a series of long-standing wells. the operator is performing a number of chemical squeeze procedures to regain production levels by cleaning up the well, and requires pinpoint data acquisition to ensure the safety and efficiency of the work.

the key parameters the operator wished to measure and record in the project were temperature, flow and density. Eztek developed the Zone 1 certified TallyBook to meet the client’s criteria, as well as that of the eU’s AteX directive on equipment that can operate in explosive atmospheres.

the Zone 1 tallyBook was subsequently mounted on the pumping skid and attached to the required sensors. it became apparent very quickly that the information delivered by the unit was invaluable on many levels. it not only allowed the water-chemical mix to be read in real time, but could also be adjusted, thus giving the best possible results immediately.

Furthermore, eztek’s application offered the operator the ability to download the data that was acquired for analysis. this is an especially advantageous feature for operators working in hazardous areas as it stores the data to be examined and can be retained as a history of the well.

EfficiencyThe most obvious benefit offered by the TallyBook DAQ units is the time saving efficiencies that they offer. Previously, a chemical squeeze procedure on an old well would have to be carried out every six months. But with the application of eztek’s technology, the expected time until the next intervention could be up to 15 months.

The TallyBook also offers project-planning benefits. Using the technology, it is now easier for operators to gauge the amount of chemicals needed for each process, thus reducing the need for unnecessary stock with lower logistical costs offshore.

In Touchthe latest addition to eztek’s range of measurement and control instrumentation is the tallyBook touch. the unit is a Zone 2-rated DAQ system with the same recording features as its siblings.

eztek measures up

However, the addition of a 10.4-inch (264-mm) touch screen makes it versatile and simple to use as the operator can swiftly switch from graphical to digital display.

Applications for this unit range from coil-tubing operations for measuring pipe heavy/pipe light to depth and pressure. the tallyBook touch is also adaptable to pumping equipment that allows for a Zone 2 unit to be employed.

eztek promises its clients a dedicated after-sales support experience, with the company’s in house software development team on hand to deal with any permutations thrown up by the tallyBook units during operations in the field. Most software updates can be done via email and sent to anywhere in the world. this makes the tallyBook an essential piece of kit for operators working in hazardous environments across the globe that are looking to cut costs and save time.

Eztek also produces a wide range of safety and efficiency enhancing products from intercom and video systems to wireline panels. n

Contact:Mervyn Newberry, Business Development Managermervyn@eztek.co.ukTel: +44 (0)1224 798829 Mobile: +44(0)780 242 9975www.eztek.co.uk

InnovOil by vNewsBase August 2012page 8

ReD Spider has developed a range of new technology for operators in the oil industry to tackle challenging intervention and completion work with a view to mitigating risks and cutting costs.

The UK-based company’s flagship innovation, eRED®, is a downhole computer-controlled valve that can be opened and closed multiple times by remote control without the need for intervention. the tool has been designed as part of Red Spider’s Remote Open Close technology product line, which aims to save time and money whilst simultaneously removing risk during operations.

Solutionsthe Remote Open Close technology product line consists of eReD, eReD-FB (a tubing-mounted, full bore version of eReD) and PowerBall® (a formation isolation valve). Each tool has an integrated power supply and electronic control module so it can carry out pre-programmed instructions either autonomously or by reacting to a command from surface.

the driving force behind Red Spider’s intervention-less technology is a need within the industry to cut rig times and costs by simplifying

look! no wiresRed Spider has developed innovative remote-controlled technology for oil companies to tackle challenging intervention and completion work

Our eRED valve reduces wireline runs - saves time, saves money and removes risk from well operations.

eRED®

in a league of its own

and counting100 runs

Jim Rohn

You hit home

chance but bypreparation

runs, not by

redspiders.com

well completions and workovers via the removal of wireline runs. This in turn makes the operation more efficient and safer.

in order to provide solutions to those problems, the 70-strong Aberdeen-based company has invested heavily in R&D with backing from the oil and gas industry technology Facilitator (itF). this investment, allied with close interaction with operators and industry bodies, has enabled it to develop its suite of open-close technology tools that are designed to deal with the particular challenges thrown up by completion and intervention work.

the company’s breakthrough eReD valve has now been used in excess of 100 times in the field by over 20 oil companies. Operators that have used the technology have reported savings of more than US$500,000 during a single subsea completion operation, typically reducing slickline runs from eight to one. in deepwater workover operations, savings of up to 36 hours and US$800,000 have been recorded in a single job.

eReD is normally pre-installed or deployed below a carrier such as a wireline lock. in practice, it works exactly like a wireline plug but without requiring any intervention to deploy or retrieve it when a barrier needs to be put in place or removed.

InnovOil by vNewsBaseAugust 2012 page 9

Tubing Hanger

Standard Lock 4.875 in

eRED

Tubing

Production Packer

Standard Lock 4.313 in

eRED

Tubing

Any application where a wireline lock and plug are used can be replaced by an eReD valve, thus achieving exactly the same results without the need for repeated intervention jobs. this removes the risk and cost associated with multiple slickline runs.

An eReD action, such as opening or closing, is initiated only when a specific well condition (known as a trigger) is detected. Upon successful completion of that action, the eReD can look for another trigger, which in turn initiates the next action. Using a series of different trigger and action combinations, the eReD can be used in complex well programmes, opening and closing as many times as required without any intervention.

the next product in Red Spider’s Remote Open Close technology line is the eReD-FB, which is the tubing-mounted version of the eReD. it consists of a remotely actuated full-bore ball valve that can be opened and closed multiple times, controlling flow through the tubing without the need for any umbilical control line.

the use of eReD-FB completely eliminates the requirement for any wireline runs during a completion placement operation, resulting in savings of between 32-38 hours and US$600,000 to over US$800,000 in subsea operations. Moreover, a mechanical downhole barrier is present at all times during operations, to be activated 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 wells on stream sooner and reducing the risk of exposure to bad weather.

When closed, the eReD-FB provides a bi-directional downhole barrier, capable of holding up to 5,000 psi from above or below. When open, the large internal diameter maximises production or injection and allows easy access to the well and equipment below the valve. Another Red Spider innovation, PowerBall, is a reservoir isolation barrier designed for reliability in debris-laden environments. it is intended to be run open, then subsequently closed during lower completion deployment and finally to be re-opened permanently by remote command for production or injection to commence.

Remote opening of PowerBall happens with no pressure cycles, but on detecting a specific trigger, much in the same way as with eRED. This in turn results in a much more flexible and efficient operation.

Savings of up to 12 hours can be achieved thanks to the efficient activation method of PowerBall. All the moving parts are placed below 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 debris can result in operational failure and costly shutdown time. By moving the mechanical parts of the ball mechanism below the closed ball area of the tool, and as a result protecting them from debris, PowerBall offers maximum reliability in dirty environments. Avoiding remedial action caused by failure of a fluid loss device can result in savings in the region of US$2 million.

eReD and its sister applications are particularly suited for deepwater and subsea work, where rig-time savings are most valuable. this makes the products especially suitable for deployment in the north Sea, Brazil, Gulf of Mexico, West Africa, Australia and Asia-Pacific, where deepwater oil exploration is ramping up rapidly. n

Contact: Red Spider TechnologyPeregrine Road, Westhill, Aberdeenshire, AB32 6JLTel: +44 1224 275000 www.redspiders.com

InnovOil by vNewsBase August 2012page 10

SeneRGy, 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™ with

much enhanced visualisation and interpretation tools aimed at giving the reservoir operator increasing ability to characterise reservoirs, whether new or mature.

Until now, reservoir modellers would have sourced image log analysis or sedimentology services from a third party, and then had to cobble together a reservoir model by bolting these separate components together into a statistical illustration of how a reservoir might be expected to behave. the new release of iP™ enables enhancement of the model from illustration to prediction.

iP™ contains an image log Processing and Analysis module, which fully covers the workflow from raw data processing, speed correction, image enhancements, thorough manual and automatic picking, through to statistical analysis of the results, including stereonet analysis. High resolution pseudo images of the borehole wall are produced from petrophysical measurements that allow geological and drilling related features in the borehole to be identified, interpreted and, importantly, oriented. This data helps build a greatly improved static reservoir model, and so gives reservoir engineers a better understanding of a reservoir’s dynamics and viability, maximising returns.

Also new is the navQC module to correct bad navigation data, Dual OBMi support and an interactive, high resolution 3D engine for visualisation of image logs.

Another new component for iP™ is nDPredictor, which has been designed to address highly nonlinear geological data and is based on a Geological Differential Method (GDM). this integrates various forms of data, preserving geological identity, to produce a true point by point solution of the selected target parameters. nDPredictor produces a deterministic solution in comparison to the statistical methods which can only produce a realisation.

A further win for iP™ is the picture it gives Geomechanics and Production engineers of the likelihood of rock failure in sandstone reservoirs and hence the chance of sand production in the well. Calculations can be run for an open hole or a cased and perforated completion, and for any well azimuth and deviation. iP™ can analyse multi-depth situations, allowing the user to predict the onset of sand failure across the whole reservoir, or it can be set to “discrete

reaching deeper for reservoir knowledgeSenergy’s iP package provides operators with a chance to move into a new age of reservoir prediction

depth,” to predict the sand-free operating envelope for a range of rock strengths and well completion options.

IP™ is now also equipped with a variety of workflows for organic shale reservoirs, plus general speed and memory improvements.

Senergy provides static and dynamic reservoir evaluation and solutions which can cover the complete cycle for a reservoir from exploration through appraisal and development to ‘brown field’ redevelopment.

the Aberdeen-headquartered company, with over 550 staff located around the world, is continuing to expand its global footprint, and can point to a proven track record in this field. Multi-disciplinary teams are often mobilised to undertake specific geological projects for the client. Recent examples include an integrated project in the neuquen basin, Argentina, where Senergy technical staff were involved in optimising facilities from the reservoir to the separation facilities and in a number of mature north Sea fields where integrated Senergy technical teams worked with operators to optimise infill locations and re-completions.

Senergy’s view is that rather than going to several different companies that specialise in one or two things, it offers the whole package under one roof. n

Contact:Senergy, 15/16 Bon Accord Crescent, Aberdeen AB11 6DE, UKTel: +44 1224 213440email: info.uk@senergyworld.comweb: www.senergyworld.com

Filename: SURVITECneg_PMS.eps Colourway: •100% Pantone PMS 158c •100% Opaque White

Survitec Group

Survitec House, Kirkton Drive, Dyce, Aberdeen, AB21 0BG, United KingdomTel: +44 (0)1224 214460 / Email: info@survitecgroup.com

www.survitecgroup.com

ENHANCINGPERFORMANCEIN THE MOST EXTREMECIRCUMSTANCES• 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

innovoil_ad.indd 1 02/07/2012 16:41

InnovOil by vNewsBase August 2012page 12

SOMe 80 years ago oil producers trying to transport natural gas in cold climates made an uncomfortable discovery. When natural gas and water come together at low temperatures water molecules rearrange to form a ball-like

cage around a gas molecule, producing gas hydrates. Hydrates are solid, and relatively stable, so form large immobile plugs inside pipelines. Apart from obstructing the gas flow, operators found that clearing the blockage by heating created serious risks of a catastrophic release of gas in a runaway Pvt event.

A problem that was occasional, even exotic, in the 1930s, is now commonplace. Deepwater wells and export pipelines work in an ambient temperature of near zero, even in warm climates. Shallower plant also finds itself near freezing in winter, and of course onshore gas is being produced in locations where zero would be a balmy summer’s day.

Apart from complete water removal (difficult!), the generally accepted solution is to add chemicals that act as hydrate inhibitors to change the conditions at which hydrates can form. the most commonly used inhibitors are methanol and ethylene glycol (MeG), which act to reduce the temperatures at which hydrates are stable. Other solutions are to use Kinetic Hydrate inhibitors (KHis) which extend the time it takes for hydrates to form, or Anti-Agglomerants (AAs), which don’t stop hydrates forming, but limit their size and prevent clustering and deposition long enough for the system to enter a warmer environment.

the bad news, of course, is that these additives are not free, and must be transported, stored and pumped to the point of origin of the gas flow for injection, making their use even more expensive. Given that natural gas is already a relatively low value material, the economics of hydrate prevention is a major concern to a gas producer, and can even turn a good field into a bad one. In extreme cases, the inhibitor requirements may be greater than 50% by weight of the produced water in a gas pipeline.

in current practice, the amount of hydrate inhibitor needed to protect a system is calculated based on the hydrate phase boundary for the specific fluid composition (of gas, oil, water and salt) being transported and the predicted worst case temperature and pressure operating conditions. Other factors must also be considered, such as the loss of some of the inhibitor, owing to its own phase changes from liquid to gas. to counter the uncertainties for a given system, a large safety margin is normally applied to minimise the risk of hydrate blockage, with the net result being that presently the industry is using far more inhibitor than it needs to. this has

no inhibitionsOptimising hydrate inhibitor injection with HydraCHeK

unpleasant consequences for the Capex costs of installing plant to handle the inhibitors, and Opex costs for it to the point of origin, injecting it and ultimately recovering or disposing of it.

Hydrafact, a spin-out company from the world-class hydrocarbon research campus of Heriot-Watt University in Scotland, has worked with BP, total, Chevron, Statoil and Petronas to develop a technology to cut these costs, without compromising either operational safety or performance.

the result is HydraCHeK, an analytical tool to give producers fast and accurate measurements of the hydrate inhibitor, and salt concentrations from produced water samples. this data when combined with the hydrocarbon fluid composition is used to find the actual phase boundary for the system being tested.

Using acoustic velocity and electrical conductivity tests on downstream produced water samples, an Artificial

neural network, and a proprietary thermodynamic model, HydraCHeK correlates results to

produce accurate predictions for the hydrate phase boundary of a system. Combined with the operating pipeline temperature and pressure the actual

degree of inhibition and safety margin for a system can be easily determined. All of this is done by a robust field-capable unit, within 10 seconds of measurement.

The result? With a much more representative picture of the hydrate risk and inhibitor effect, the pipeline operator is now able to optimise the amount of inhibitor, and to understand much more clearly what their safety margins are (obviously, the size of the safety margin is the choice of the pipeline operator, and HydraCHeK gives the operator better knowledge to make that choice).

in practice, using HydraCHeK very quickly results in greatly reduced

inhibitor use. in a recent application on a platform in the north Sea, the operator proved that existing inhibitor levels were well above those actually required – in short, the system was being hugely over inhibited. Utilizing HydraCHeK the operator was able to roughly halve their inhibitor injection, with no loss of safety, and a nPv of savings calculated at above £10m (US$15.7m).

HydraCHeK is currently being deployed by total, ConocoPhillips and Dolphin energy. n

Contact: Tom Gorlach, Hydrafact Ltd.email: tom.gorlach@hydrafact.comTel: +44 131 449 7472 Web: www.hydrafact.com

InnovOil by vNewsBaseAugust 2012 page 13

EDinBURGH-BASeD e-products, a business solutions developer, is in the final stages of developing a suite of software solutions for use across the oil and gas industry.

The firm was commissioned by engineering consultancy Optimus to design e-planner, which is being used to manage and control all of the latter’s 193 current projects.

various modules make up the fully integrated e-planner system, with e-products currently at work developing the final phase of the system – invoicing. Once this has been launched in early September, the company intends to release the software to other companies searching for efficient project planning tools.

the e-planner system provides oil and gas companies with a comprehensive tool to manage projects from initial estimate phase through to completion, helping them to come in on time and budget.

e-planner relies on its integrated nature to save time and avoid error, while saving users from having to switch manually between several separate systems. e-planner not only reduces administration overheads but also provides greater visibility throughout a project’s lifecycle.

e-planner was conceived two years ago and commissioned by Aberdeen consultancy Optimus, which provides process, facilities and safety engineering, and project execution. Optimus had searched for a single system to manage all of its projects while tightening up project controls – and having failed to find such a platform commissioned e-products to build one. in 2011 Optimus reported record sales of over £10m (US$15.7m), and pre-tax profits of £900,000 (US$ 1.4m), using e-planner as its core project management software.

e-planner is a fully integrated system, whose various modules

thinking ahead with e-plannerUK firm e-products is designing a suite of software solutions for use throughout the oil and gas industry

can also be employed independently. the costing module allows companies to estimate and tender for projects easily, enabling managers to keep on top of projects via comprehensive dashboards and reports. A fully audited variations system also allows for mid-project budgetary changes.

Scheduling is synchronised with Oracle’s Primavera P6 enterprise Project Portfolio Management, and for companies that do not use Oracle, e-planner has an inbuilt scheduling module. E-planner can be configured to send automatic reminder emails to trigger data entry (for example timesheet entry). Moreover, project managers are able to vet times if required. these features can help remove bottlenecks while reducing billing errors.

the absence module allows managers to track absences – such as planned contractor absences and staff holiday entitlements – on a companywide basis, allowing for greater planning of project resources. A Microsoft Outlook add-in allows central filing of important project emails, which can then be accessed by the entire team. the contracts module ensures that renewal dates are never missed, by sending notifications of any contracts that require attention. Contract documents are also securely stored so they can be easily referenced. The invoicing module reduces errors, identifies bottlenecks and increases cash flow by automatically generating invoices from project data. n

Contact:Trevor Cattleemail: trevor@e-products.co.ukTel: 0845 009 4050web: www.e-products.co.uk

Oil SpillDetection &MonitoringHydrocarbon Oil SensorsProven range of in-situ sensors optimisedfor monitoring crude and refined oil fromcoastal margins to deep ocean.

Chelsea Technologies Group Ltd+44 (0)20 8481 9000sales@chelsea.co.uk

www.chelsea.co.uk/Oil.htm

Configurable fluorimeters

Targeted spectral response

Oil spill monitoring

Pipeline leak detection

Environmental remediation

Long term monitoring

Delivering Now

InnovOil by vNewsBaseAugust 2012 page 15

UK-BASeD Chelsea technologies Group’s range of in situ fluorometers have been used in the offshore industry since 1990. Originally developed for military applications, the Uv Aquatracka has the ability to

detect very low levels of hydrocarbons to depths of 6,000 metres. the newly launched Uvilux is designed for shallower depths (600 metres) but now yields equivalent sensitivity performance. Both instruments are capable of detecting crude and refined oils in the marine and freshwater environment and are in use around the globe.

“there has been unprecedented demand for our hydrocarbon detection sensors following the oil spill in the Gulf of Mexico,” Bruce Kimber, Chelsea’s customer services manager, told InnovOil. He went on to say that: “More recently we’ve been contacted to supply the Uvilux hydrocarbon sensor to monitor potential spillage during the procedure of offloading the ship’s fuel from the stricken Costa Concordia vessel in italy.”

Monitoring authorities tend to select the Uv Aquatracka because of the robust measurements offered by the fluorometer, as well as its unparallel sensitivity and full ocean depth capability.

Recent work within Chelsea’s R&D department has now yielded equivalent sensitivity performance from the Uvilux in-situ fluorometer. This UV LED fluorometer is smaller and lighter than the 6,000m rated Uv Aquatracka. the Uvilux provides a depth rating of 600 metres and offers a high specification in-situ hydrocarbon sensor at lower cost. The UviLux can be configured for measurements of crude oil, refined oils or CDOM for other applications. n

Contact: Ellen Keegan, Chelsea Technologies GroupTel: +44 (0)20 8481 9019.

casting a critical lightMeasuring hydrocarbons in tough conditions can be a difficult job but Chelsea Technologies’ fluorometers are up to the task

4

The general assembly of AQUA III is shown in Figure 1. The instrument comprises four major subassemblies: a) A Turret Assembly that houses

the optical components and makes the front cap for the Pressure Housing.

b) An Electronics Chassis that contains: the signal circuits of the instrument. the light source and its power supply.

c) A Pressure Housing that encloses the Electronics Chassis.

d) A Rear End Cap that is used to seal the Pressure Housing.

The turret has two plain bores machined into it, one bore houses the excitation optics, the other the emission optics. The optical components consist of a series of lenses and filters and, on the detection side only, a photodiode. Each bore runs parallel with the length of the instrument and is optically linked by a prism mounted separately in the top section of the turret. The lenses, filters and photodiode are held in their correct axial positions by a set of spacers. The optical layout is shown in Figure 2.

aQUatracka iii assemblyaQUatracka iii (left) and its new sibling, Uvilux

Centrum House108-114 Dundas StreetEdinburgh EH3 5DQ

NewsBase LimitedTel: +44 (0)131 550 9294web: www.newsbase.com

Allan MillerMedia Sales Manageremail: sales@innovoil.co.uk

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.

adrok’s atomic dielectric resonance scannerMapping deep surface geology with electro magnetic radiationPage 3

look! no wiresRed Spider’s Remote Open Close Technology Page 7

HigHer sensitivityChelsea Technologies’ fluorometers deliver Page 14

deepwater testingShawCor’s SSV predicts pipeline performance Page 4

Published by vNewsBase

Pilot issue

July 2012

Bringing you the latest innovations in exploration, production and refining

™