DNV GL has various efforts under way with oil companies as industry works to embrace digitalization technology and standardization to improve productivity and help reduce operating costs.
Lundin Norway and DNV in August said they developed the first step toward forecasting unplanned shutdowns of Lundin Norway's Edvard Grieg platform within the Utsira High area in the Norwegian North Sea.
The platform and associated infrastructure, on stream for 2 years, is equipped with more than 2,000 sensors. Lundin Norway is the operator with 65% interest. Partners are Wintershall 15% interest and OMV 20% interest.
Lundin and DNV engineers worked with four students on a project to use data analytics to detect events that might cause an unplanned shutdown. Another goal of the data analytics was to initiate necessary preventive action.
Kjell Eriksson, DNV oil and gas regional manager, Norway, said, "We've seen similar results in several other digitalization initiatives we've had lately. Engineers with domain knowledge of oil and gas operations are critical to complement the data analytics approach."
The students created statistical models that they trained using the data generated by sensors. They built a computer program to analyze the results of each statistical model.
Subsea documentation
Previously, DNV directed a joint industry project (JIP) standardization collaboration that resulted in a recommended practice (RP), DNVGL-RP-0101, covering technical documentation for engineering, procurement, and construction phases of subsea projects.
JIP participants wanted to establish a set of minimum paperwork between oil companies, contractors, and suppliers.
Industry devotes much time and numerous staffers to assemble technical documentation.
"If we were to quantify the replications across the supply chain, we could realize that many of these activities add very little or no value to the safety or performance of the subsea equipment and systems," said Martha Viteri, DNV head of subsea and well systems.
Jan Ragnvald Torsvik, Statoil's lead engineer of life cycle information and JIP co-chair, said Statoil benefitted from implementing a draft RP version in the Johan Sverdrup project, which is under construction in the Utsira High area with production expected toward yearend 2019.
He said the RP "will dramatically cut waste in handling technical information...this standard's approach in utilizing package specific requirements has a positive impact on standardization, efficiency, and quality."
A contractor in the JIP said subsea documentations increased by fourfold during 2012-15. The Norwegian Oil & Gas Association and Petroleum Safety Authority Norway were JIP observers.
In addition to Statoil, JIP partners included: Aker Subsea AS, Centrica Energi, Det Norske Oljeselskap ASA, DNV GL, FMC Technologies, GE Oil & Gas, GDF SUEZ E&P Norge AS, Kongsberg Oil & Gas Technologies AS, Lundin Norway AS, Oceaneering, OneSubsea, RWE Dea Norge AS, Subsea7, Subsea Valley, and Suncor.
Verification services
DNV also is testing a remote surveillance service for subsea equipment manufacturers. Both contractors and operators seek improved safety and increased flexibility on testing schedules for surveys and inspections.
Viteri said DNV has developed protocols to optimize an interface between cameras and software. The camera can be manually operated or installed on equipment. The camera is focused on critical equipment points and its feed is transmitted to a surveyor's or inspector's office, cutting travel costs.
"Pilots show clearly that remote witnessing is an acceptable tool for independent surveillance when suitable conditions are met," Viteri said. "With remote witnessing, operators purchasing subsea equipment can now observe vendor tests as they happen."
Previously, operators relied on third-party observers.
