Technology & Product News

James Fisher Mimic Provides Its Specialist Condition Monitoring Software to Stolt Tankers

12JamesFisher Stolt PR pictureJF Mimic, part of James Fisher and Sons plc, announces it has signed an agreement to supply its specialist Mimic condition monitoring software to Stolt Tankers B.V (Stolt) - which operates the world's largest and most sophisticated fleet of chemical and parcel tankers, to enhance operational safety and improve the technical reliability of its assets.

The Mimic software will be installed on Stolt’s fleet of 75 vessels, as well as onshore at its head office, to provide instant condition status alerts along with detailed efficiency monitoring, as management and control of a 21st century maritime business demands unique solutions, designed to supplement the existing ship operating procedures along with the challenges of managing a complex fleet.

Aspects of the standard Mimic condition monitoring software suite have been further developed to satisfy these demands by enhancing the software to allow raw operating data from various sources, such as the main and generator engines, cargo pumps and other auxiliary machinery, to be collected onboard and sent automatically to the Mimic application at Stolt’s head office pushing alerts to users. Further analysis can also be conducted across machinery and vessel types allowing Stolt to make informed maintenance decisions.

Andres Casanova, Stolt’s Maintenance and Reliability Manager said: “Mimic was the ideal choice for collecting, validation and the visualisation of digitalised data. The company vision is to facilitate easy access for all relevant stakeholders, both at sea and ashore. It will empower the organisation to take the lead with regards to proactive intervention of in-/de-creasing trends or exceeding threshold values. This will further enhance our operational safety and improve the technical reliability of our key assets.”

Stolt’s version of Mimic allows it to have full oversight of its vessel operations combined with a condition statement for its critical machinery and assets. The installed Mimic system provides limitless possibilities to the maintenance and operations managers to incorporate various tasks, from typical maintenance routines, calculations and reports to use when assessing individual asset, system and vessel condition; and then, uniquely, use the efficiency statement as a trigger (threshold alert) for maintenance.

The system also integrates spectrographic oil analysis results, asset condition reports, such as feed water purity and cathodic protection reports, into one easy to view dashboard from which managers can extract a wealth of real time information.

Martin Briddon, Business Development Manager of James Fisher Mimic explains: “This Mimic software suite offers all the necessary tools for robust data manipulation and in depth analysis of every maintenance task. Connecting vessels to a central hub is now achievable, leading to full control of your fleet from one system.”

The collected data is always available on the vessel’s Mimic system, as well as on the shore Mimic system. Having the option to import data in the system either manually or electronically offers flexibility, and the automated procedures help to effectively reduce the time and effort spent.

The deployment of the system was implemented remotely, and all the databases creation, specifically for each vessel, is implemented from the shore. Data is flowing in both directions between the Mimic ship and the Mimic shore system, providing a perfect communication between shore and ship side.

VisualSoft Selected for the World’s Most Advanced Cable-Laying Vessel

14VisualSoftForum Energy Technologies, Inc. has announced a new contract that will see its market-leading pipeline and cable survey software installed on the world’s most advanced cable laying support vessel, the NKT Victoria.

Two VisualSoft Four Channel High Definition Digital Video Systems (VisualDVR MCHD) will be supplied to iSURVEY Group, a leading provider of survey and positioning services to the global oil and gas and telecommunications sectors. The first vessel installation for the newest system in the VisualSoft range, is to be utilized on the NKT Victoria in the Moray Firth.

The NKT Victoria (DNV-GL Class) is a 140m x 30m DP3 top-of-the-range diesel electric vessel with 1600m2 of deck space and two large offshore cranes. The high capacity cable lay system features a battery energy storage system to assist the cable loading in the event of failure of the shore power used during loading.

The Caithness Moray High Voltage Direct Current (HVDC) project in Northern Scotland is the largest investment in north Scotland’s electricity network since the hydro development era of the 1950s. It will see the electricity grid on either side of the Moray Firth connected via a new submarine cable capable of carrying up to 1,200 megawatts of electricity, equivalent to the electricity needs of about 2,000,000 Scottish people. This major project aims to help Scotland transition towards a low carbon economy.

Andy McAra, VisualSoft’s Product Director said: “We are very excited to release our new multi-channel high definition video solution to the market and it is great to be supplying the first of these systems to iSURVEY who we have had the pleasure of working closely with for many years.”

“It also makes us very proud to see our systems being installed on this new state of the art cable lay ship not least because her first contract will be here in Scotland.”

Kenneth Leverskjær, iSURVEY’s Project Manager said: “We have great expectations to the VisualSoft system, and are looking forward to further develop the strategic relationship with FORUM Energy Technologies as provider.”

Paul Mccormack is the Offshore Construction Shift Supervisor on the new NKT Victoria vessel. He said: “The NKT Victoria was designed and outfitted to be the very best. The latest VisualSoft HD digital video system was therefore an obvious choice to add as part of this state of the art cable lay vessel”.

The VisualSoft suite is a modular range of software applications designed specifically for use during subsea structure and pipeline inspections.

The VisualDVR MCHD system will provide the project team with up to four channels of high definition video recording complete with built in dynamic overlay and the ability to distribute live video and overlay channels without the need for additional hardware. Video files are recorded using H.264 encoding for optimum storage efficiency and playback compatibility.

In recognition of the widespread use of H.264 as a recording format within the subsea industry, VisualSoft has released an unlimited codec-free player for use within their editing suite, VisualEdit, and the viewer, VisualReview. The player has improved window handling to allow optimum use of high definition video playback.

Also within the scope of supply is VisualArchive, an application which is used to collect logged files from the video systems and copies them to pre-configured file locations on a variety of storage and backup devices such as large network storage drives which also form part of this scope.

VisualEdit Eventing will be used to provide an offline event and anomaly logging, editing and reporting capability for the project.

Ampelmann Introduces the A-type Enhanced Performance Motion Compensated Gangway

10Ampelmann A EPAmpelmann has announced the launch of its latest gangway for personnel transfer: the A-type Enhanced Performace (AEP). Now providing clients with 10% greater workability in sea states up to 4m significant wave height; the AEP also has the ability to use smaller vessels to obtain similar performance (compared to current A-type).

The AEP features an advanced motion compensation control system with precision controls to enable fast landing and comfortable people transfers. The system significantly improves operational up-time on projects year-round and provides benefits to operators in rougher waters, including the North Sea and the coasts of South America and the Middle East.

The AEP can also be used to ensure comparable workability on a relatively small vessel, where bigger vessels were needed before, saving cost for Ampelmann’s client by allowing flexibility in positioning on the vessel.

Falcon 9 Rocket Booster Returns to Port Canaveral

10Falcon 9 Rocket BoosterOn Thursday, June 29, 2017, Port Canaveral welcomed back a SpaceX Falcon 9 rocket booster after its successful June 23 launch and landing aboard the drone ship Of Course I Still Love You. This was the most challenging launch for the 229-foot-tall rocket to date. The first stage rocket soared to an altitude of 44 miles before successfully separating from an 8,150-pound BulgariaSat 1 satellite.

Once the Falcon 9 first stage rocket booster has been offloaded from the drone ship, it will make the short transit to SpaceX’s new rocket refurbishment facility some 700 yards away. SpaceX is planning to launch its third Falcon 9 rocket in less than 10 days, scheduled for Sunday evening, July 2nd.

ABOUT PORT CANAVERAL

Led by the elected five-member Canaveral Port Authority Board of Commissioners and Port Director and CEO, Captain John Murray, Port Canaveral is one of the world's most dynamic and exciting ports. A world-class gateway for cruises, cargo, recreation and logistics, as well as a gateway to new frontiers, including space, Port Canaveral hosts more than 4 million revenue cruise passengers through its state-of-the-art terminals and 5.5 million of tons of cargo annually, including bulk, break-bulk, project, and containerized. The Port is strategically located to service all Florida markets, as well as the Southeastern United States. In addition to world class cruise facilities and diverse cargo operations, Port Canaveral offers more recreational opportunities than all other Florida deep-water seaports combined, including public parks, free public boat ramps, marinas, an entertainment district, and the seven-story interactive exhibit and event venue Exploration Tower. For more information or to download high resolution versions of the photos, visit the Port Canaveral website.

A New Way to Fight Piracy on the Open Sea

12state of piracy 2016 logo bannerThe economic cost of maritime piracy is on the rise once again as Somali pirates resume attacks on ships and resorting to old tactics of ransoming crew for money. The State of Maritime Policy Report 2016, released last month by Oceans Beyond Piracy (OBP), states the economic cost of piracy caused by groups out of Somalia increased to $1.7 billion in 2016, from $1.3 billion in 2015.

Piracy had been on a steep decline since 2010 due to increased security efforts and precautions taken aboard ships. However, in the past few years, per the OBP report, there has been decreased vigilance by the shipping community such as hiring smaller private security teams and taking less security measures aboard ships. In 2017, only halfway through the year, there have already been two hijackings including a tanker and a commercial ship. Read the full report from OBP.

A solution to the rise in piracy is not just to increase the number of security personnel aboard ships, but to also outfit the ship with surveillance technology which will allow them to take the precautions necessary to avoid a conflict. Electro Optical Industries’ line of 360-degree panoramic view infrared thermal cameras, Spynel, are able to detect and track targets that could present a threat to a ship and its crew. They act as optical radars but can pick up targets that radar could not detect, such as small wooden and rigid inflatable boats up to the horizon. The Spynel cameras can successfully operate at sea state level 5/6 (rough to very rough sea) thanks to an autonomous gyro-stabilized platform and in addition to mechanical stabilization, Spynels come with a sea-specific image processing stabilization algorithm. Spynel are currently deployed on ships and at ports around the world to combat against theft, piracy, terrorism and espionage.

An optional software module enables the display AIS (Automatic Identification System) data from boats in the thermal panoramic video. The automatic thermal detections and the AIS data can be fused to generate alarms only for instance objects without AIS transmitter, like a pirate. (Requires an AIS receiver)

About the Company: Electro-Optical Industries is a world leader in electro optics and infrared test equipment, thermographic cameras for process control monitoring and infrared wide area surveillance systems. Founded in 1964, Electro-Optical Industries has products in over 80 different countries with a customer list of over 10,000, including some of the best-known companies worldwide.

Hydrex Mobdock Reduces Singapore Sterntube Spill

It is estimated that damaged ship sterntubes are leaking some 57 million tonnes of lubricating oil in to the oceans every year, but by replacing these seals when the damage is first discovered, Hydrex in-situ repairs not only help towards reducing the environmental impact but can also save shipowners time and money.

15sterntube repairs low resUsing its flexible mobdock technology, damaged aft sterntube seals can be quickly replaced underwater during a vessel’s port-stay, negating the need for costly drydocking. Even complicated sterntube configurations and liners can be repaired this way.

Photo credit: Hydrex

“Environmental considerations are frequently demanding that damaged sterntube seals are repaired as they happen and in the shortest possible time frame,” said Hydrex Production Executive Dave Bleyenberg. “Every Hydrex office is equipped with the mobdock technology and sophisticated equipment that can be deployed at a moment’s notice to effect repairs in any location around the world.”

A recent sterntube seal replacement Hydrex engineers completed in Singapore underscores the commercial and environmental benefits of using the in-situ repair method.

When a 138m long LNG tanker began leaking oil from a damaged sterntube seal during the vessel’s port of call, an expedient repair was required to avert any delay to its schedule and prevent further pollution.

“Such incidents not only result in off-hire costs and charges, but also pollution related fines,” said Bleyenberg.

Hydrex’s local mobdock team was deployed while the company’s technical department in Antwerp, Belgium, put forward a detailed repair plan which, once approved, allowed the mobdock team to make all necessary vessel preparations. Within a matter of days, diver/technicians were on-site carrying out the seal replacement work.

Working in concert with the original equipment manufacturer, the Hydrex team removed and replaced three damaged seals with new ones. The entire operation was carried out underwater, without the need to drydock the vessel and without disruption to the vessel’s schedule.

“From the start to finish, the project took just a few days, preventing any further oil leaks and keeping the vessel operational without incurring significant costs,” said Bleyenberg.

Gas Safety Top of the Agenda for Martek Marine on US $3 Billion Offshore Project

Maritime industry technology specialists Martek Marine are setting the bar high when it comes to offshore gas safety. The company has developed a first-of-its-kind gas sampling system for a new moored floating production unit, which forms part of the Jangkrik Complex gas fields development in Indonesia. The system has been developed to dramatically improve offshore crew safety through the use of advanced gas sampling technology.

11Gas Sampling System copyA first of its kind gas sampling system. Photo credit: Martek Marine

The worst offshore disaster in history, the Piper disaster on 6 July 1988, involved a series of gas explosions which destroyed the Piper Alpha oil platform in the North Sea, killing 167 men. According to the latest statistics from the Health and Safety Executive, to this day, a third of all dangerous occurrences occurring offshore relate to gas releases. Explosions, following a gas release are a major offshore hazard due to the catastrophic consequences that tend to result; taking life and impacting the health of workers; pollution of the environment; direct and indirect economic losses, and deterioration of the security of energy supply.

Early warning is key when it comes to the prevention of gas explosions. Failure to avoid ignition of released hydrocarbons is best achieved through the installation and functioning of gas detectors in appropriately defined hazardous areas. The offshore accident report ‘Lessons from Past Accident Analysis’ from the European Commission, advises that a vital step in controlling major offshore hazards is the installation of, ‘state-of-the-art gas detectors in appropriate locations, extending to hazardous areas where necessary.’

It’s not then surprising that gas safety was at the top of the agenda for the new, highly-regarded and large-scale offshore engineering project in Indonesia. The Jangkrik Project comprises of the development of the Jangkrik and Jangkrik North East gas fields, referred to jointly as the Jangkrik Complex. Approximately 400m deep, the Jangkrik Complex forms part of the deep-water Muara Bakau block in the offshore Kutei Basin, situated 70km from the coast of East Kalimantan.

Following drilling at three exploration wells, Jangkrik 1,2 and 3, a feasibility study completed in July 2011, led to selection of the most appealing concept for development of the area. The chosen approach is based on a subsea development with 10 wells and full treatment facilities on a spread moored floating production unit (FPU). The FPU has an export line to shore at Sapi Landfall.

In 2014, energy company Eni awarded offshore engineering experts Saipem, the engineering, procurement, construction, and installation contract for the new FPU, valued at US$3 billion. The shipping division of Hyundai Heavy Industries (HHI), who currently hold a 15% share of the global shipping market, built the FPU hull in Ulsan, South Korea, whilst further fabrication work for the topsides was carried out by Saipem in Indonesia, with Saipem’s Execution Centre in Jakarta managing the overall project.

Gaining international interest thanks to the rapid development and short production start-up time, the project has a time to market of just three-and-a-half years from the date of the investment decision and production at the Jangkrik Complex gas fields commences in 2017.

The FPU is designed to process 450 MMcf/d (12.7 MMcm/d) of gas and condensates and is a multi-purpose unit. The Jangkrik gas volumes will supply the local domestic market, the Indonesian LNG market as well as the LNG export market providing a significant contribution to the Country’s energy needs and economic development.

In addition to being used for activities relating to the Jangkrik Complex, the FPU will also act as a hub for other sites nearby. All gas will be sent to a liquefaction plant called Bontang LNG following treatment on board and this is achieved thanks to connections to 10, deep-water subsea production wells. The final destination of all condensate from the site is the Senipah Power Plant in East Kalimantan.

Global maritime technology company Martek Marine specified a gas sampling system for the FPU which is the first of its kind. Based on the company’s well reputed MM5001 Gas Sampling System, the bespoke setup comprises of 4 independent systems. The systems are designed for the sequential sampling of hydrocarbon gas, as well as sequential sampling and continuous monitoring of oxygen. The sampling activities are focused on the ballast and condensate tanks in addition to continuous monitoring of supply headers within the FPU.

"The system will play a vital role in ensuring the safety of those onboard, by giving crew the means to effectively monitor gases within enclosed spaces and ensure that levels maintain within safe parameters." Said Martek Marine Project Engineer, Steve Austwick.

The first sampling system is a split system, designed to sequentially sample hydrocarbon (22 Point) in water ballast tanks. Equipped with the latest dual Non-Dispersive Infra-Red (NDIR) sensors, the equipment is faultless when it comes to monitoring increasing levels of methane (CH4).

Being a split system, the pump, solenoids and sensors are housed in the monitoring side of the system installed in a cabinet on deck. Benefiting from an EExe enclosure and EExd internal components the unit is explosion-proof. The human machine interface (HMI) and programmable logic controller (PLC) are housed control side in the cargo control room (CCR). In a conventional gas sampling system, the control and monitoring equipment is mounted in a single cabinet which is installed in a safe area, usually the CCR.

"The important benefit to a split system, is that the need to run sample piping into the CCR is avoided." Said Austwick.

The second system supplied is a 6-point system used for sequential sampling of oxygen in condensate tanks. In addition to benefitting from the design features of the sequential hydrocarbon gas sampling system, the addition of advanced paramagnetic sensors enables levels of oxygen to be monitored in the inert gas blanket of condensate tanks.

Paramagnetic sensor technology provides unbeaten performance and longevity.

"The sensors use no consumable parts, meaning they excel in terms of durability," said Austwick. "Offering world class precision over a range of 1% to 100% oxygen, they are able to measure the oxygen concentration not only in flammable gas mixtures, but also in low concentrations and with high precision."

Two further gas sampling systems were supplied under the contract, both continuous oxygen gas sampling units. Both single point systems, the first is designed for use in the inert gas supply header and the second, in the high purity nitrogen header.

Both systems benefit from paramagnetic oxygen sensors to monitor oxygen enrichment. Both the sensor and the pump are installed in a single cabinet.

"Having only one sample line ensures the headers are continually monitored and no front-end control is therefore required," said Austwick. "A signal from the system analyser is connected directly to the distributed control system (DCS) on the vessel, ensuring optimum reliability through localised control functions near the equipment."

All gas sampling systems are now installed and the naming ceremony of the “Jangkrik” Floating Production Unit (FPU) vessel took place on March 21, 2017 at Saipem Karimun Yard, Tanjung Balai Karimun, Indonesia. The FPU then sailed to its final destination at the Jangkrik Complex in preparation for gas processing and export, which is expected to reach a capacity of up to 450 million standard cubic feet per day (mmscf/d).

Seatronics Supports Global Oilfield Engineering Services Provider with Key Brazilian Project

12RTS Gen 5 MUX Available from Seatronics1Seatronics, a marine electronic equipment specialist in subsea services group Acteon, has supported a global oilfield provider of engineered services and products, with a key project in Brazil through the supply of state-of-the-art subsea equipment.

Seatronics’ range and expertise provided the company with a single source solution for all its equipment requirements for the project. This ease of service, combined with Seatronics ability to deliver the required range of equipment quickly, fully integrated ahead of delivery, has strengthened the long-standing relationship between Seatronics and their client.

The equipment sale was completed by Houston-based Seatronics Inc and included ROV Survey sensors, which were interfaced to Seatronics exclusive RTS Gen5 MUX ROV multiplexer. All the equipment was connected with Seatronics in house manufactured neoprene cables and the engineered solution was mobilised, system tested and delivered within two weeks to fully comply with the project schedule.

Janelle Totah, Vice President, Seatronics Inc. said: “We are delighted to have been able to support our client with this order.

“This award demonstrates Seatronics continued commitment to supporting clients with their Brazilian operations while the supply of this considerable spread displays our ability to combine industry leading products, cables, and engineering services to deliver top quality solutions for our clients, all from a single source.”

Industry Project on Standardizing Subsea Processing Boosts up to Phase 2

10DNV CLOSEUP LAPTOPSubsea processing offers great potential for the oil and gas sector, but is also a relatively young field of technology, causing costly and inefficient tailor-made solutions. The DNV GL-led joint industry project (JIP) on standardizing subsea processing aims to reduce cost in a lifetime perspective. Initially focusing on subsea pumping, the partners in Phase 1 have now concluded the functional description of subsea pumping, while Phase 2 will deliver standardized guidelines. With all the four leading system suppliers on board, new operators are still welcome to join the project.

According to DNV GL’s seventh annual benchmark study, Short-term agility, long-term resilience, subsea technology is the highest-ranked area globally for conducting R&D among emerging technologies in 2017. In addition, standardization efforts are on the rise to remove complexities, with two-thirds of respondents saying their organization will seek greater standardization of tools and processes in 2017.

Although subsea processing is a target area for innovation, operational experience has also grown in recent years, with significant developments made by, among others, Total, Petrobras, Shell and Statoil. However, the lack of standardization which is driving costs up is still seen to make subsea processing less competitive than alternative solutions.

Kristin Nergaard Berg, JIP project manager, DNV GL – Oil & Gas, says: “Subsea standardization offers tremendous benefits. It allows flexibility for tailor-made facilities at a system level through standard functional descriptions and specifications, while also increasing predictability in the value chain. This will not only lower transaction costs and accelerate implementation for all parties, but also allow freedom to innovate and employ new technology.”

The kick-off for Phase 2 of the Subsea Processing JIP was recently held at DNV GL’s headquarters at Høvik, Norway. The JIP includes system suppliers Aker Solutions, GE Oil & Gas, OneSubsea and TechnipFMC and operators Shell, Statoil and Woodside. Phase 2 is expected to lead to a guideline and eventually a recommended practice for subsea pumping systems.

Building on the concluded functional description from Phase 1, the JIP will continue by developing system level requirements and design classes, as well as harmonized work processes and design standards.

Phase 2 activities are related to:

  • Standards, functional requirements and specifications
  • System design
  • Pump modules and pressure-containing equipment
  • Control system and instrumentation
  • Power system
  • Materials and welding
  • Qualification work processes and test requirements.

Hans Christian Nilsen, Head of Boosting Technology, Aker Solutions, says: “The subsea industry is looking towards standardization for ensuring cost-efficient and reliable technology. Aker Solutions welcomes a harmonized approach with the vendors and oil companies, which will enable the future large-scale use of subsea boosting.”

Morgan Harland, General Manager, Subsea & Pipelines, Woodside, says: “Through innovation and collaboration, Woodside aims to deliver outstanding performance of our subsea and pipeline systems throughout the entire lifecycle. The standardization of subsea processing JIP and its initial focus on subsea pumping hits the mark with standardized guidelines being developed for subsea processing modules and interfaces that are efficient, reliable and readily installed and serviced. We use subsea boosting in our subsea production systems and know that these are important lifecycle cost drivers.”

Kjell Eriksson, Regional Manager Norway, DNV GL – Oil & Gas, says: “Like more conventional solutions, subsea processing must prove to be cost efficient to be considered attractive. At the same time, subsea processing will be an enabler for increased oil recovery. Through collaboration with the big players in the subsea industry, this JIP drives subsea processing towards being a competitive and viable solution for a wide range of future oil and gas fields.”

Phase 2 will be completed in 18 months.

Integrated Approach Accelerates Understanding of Petroleum Systems

11 2CGGlogoCGG’s JumpStart™ multi-client geoscience programs integrate the most advanced seismic data with reviewed, calibrated and interpreted well and geological data for petroleum systems evaluation, supported by regional interpretations and reports. The aim is to provide a single source for all the available information about an area in a consistent, accessible and ready-to-use format, in order to maximize the value of the seismic data and provide a regional context to support exploration efforts. There are seven JumpStart programs nearing completion, offshore Mexico, Brazil, Gabon, Australia, Indonesia & Timor Leste, and Norway, with more programs in the pipeline.

11 1 2CGG NorthViking LargeMiocene-Pliocene channel complex from the Northern Viking Graben JumpStart program (image courtesy of CGG Multi-Client & New Ventures).

The three major components of a JumpStart program are: the acquisition and processing, or reprocessing, of seismic data; collation and analysis of available wells, including core data where possible; and integration of this upgraded data, and other available information, into a comprehensive interpretation and evaluation of the basin’s petroleum system(s). The typical workflow starts with a regional geology review which forms the basis for the interpretation of the seismic data, basin model building, and play fairway analysis.

Well data represent true samples of the Earth and, as such, are essential to calibrate geological models. However, the number of wells available for review in JumpStart programs varies greatly, depending on the maturity of the basin and the data-release policies in the area; in the North Viking Graben, for example, 140 selected wells are being analyzed, whereas the Mexican Encontrado program uses 16. Therefore, a consistent petrophysical and stratigraphic review of the well data is undertaken to provide a robust chronostratigraphic framework for well ties. Where data is available, biostratigraphy is used to help define Consistent Stratigraphic Markers across the basin.

Previous well interpretations have frequently been found to be inconsistent, largely due to the scientific knowledge and tools available at the time the well was drilled. In the North Viking Graben, some older sands were wrongly assigned to be the Agat Formation, but closer examination of the age and composition enabled them to be reassigned and a better stratigraphic correlation was achieved between wells and seismic. Similarly, re-examination of the previous interpretation of wells in Mexico’s Encontrado program has significantly changed the understanding of the basin. Additional wells from the US Perdido area are now being analyzed to verify this. In Gabon, the re-interpretation of well data acquired through the pre-Aptian salt has revealed potential for an additional late syn-rift sand play to exist in the ultra-deep offshore area, different from the one commonly known as the Gamba sandstone.

Typically, the new stratigraphic markers and fast-track seismic data are used from an early stage to generate seismic-to-well ties to calibrate velocity models and formation markers, and are used for quality control throughout the seismic processing. The well data can also be used to generate pre-stack attributes and AVO gather synthetics which are used to control the quality of AVO signature preservation throughout the seismic processing flow.

Within this framework, additional data such as potential fields, geochemistry and satellite mapping of offshore hydrocarbon seeps are integrated into the imaging and interpretation of the seismic and the petroleum system evaluation. On completion of seismic processing, full structural and stratigraphic interpretation of the new data is performed for key horizons, and seismic attributes (pre- and post-stack) are extracted to map the potential presence of fluids and facies. Stratal Slicing on depositional horizons and spectral decomposition are used to provide a clearer understanding of lateral seismic facies and reservoir quality variations.

JumpStart data sets, comprising compiled, reviewed, and ready-for-use data with a full suite of interpreted information, comprehensive reports, prospectivity evaluation, and risk assessments, are available. Visit CGG on booth #630 to find out more about how JumpStart programs can help accelerate your petroleum systems understanding, saving you valuable time and enabling you to assess new areas more quickly.