A digital oilfield programme succeeds or fails on three things. The first is data quality: instruments that are calibrated, communications that work and data that is validated before anybody uses it. The second is surveillance logic: meaningful expected values and exception limits, so that the system raises things worth attention rather than thousands of alarms. The third is the response process: a named owner, a workflow and a way of tracking whether the exception was resolved.

Where these are missing, technology does not help. Many operators have installed real-time systems and gained nothing because the alarms were ignored, the data was not trusted or nobody's job changed. Where they are present, the gains are substantial: faster detection of well and equipment problems, less deferment, fewer field visits and better use of scarce engineering time.

Remote and collaborative working is the organisational consequence. Collaboration centres bring engineers, operations and specialists together around the same real-time picture, and allow fields to be monitored with fewer people on site. This changes roles, decision rights and competence requirements, which is why digital programmes are as much change programmes as technology projects. Cyber security is the other consequence, since connecting operational systems to networks creates risk that must be managed deliberately.

By the end of this training, participants will be able to:

• Describe field instrumentation and data acquisition requirements for real-time surveillance.
• Explain SCADA, historian and communications architecture.
• Design data integration between production, engineering and maintenance systems.
• Manage master data and data quality in real-time systems.
• Build expected value models and exception detection logic.
• Design alarms and prioritisation that engineers will actually use.
• Design automated surveillance workflows with defined ownership.
• Plan collaboration centre and remote operations practice.
• Apply cyber security principles to operational technology.
• Evaluate the value case for digital oilfield investment.

Organisations sending participants to this training will:

• Detect production and equipment problems faster.
• Reduce deferment through quicker response.
• Make better use of limited engineering resources.
• Reduce field visits and support remote operations.
• Base digital investment on measurable value rather than technology appeal.

Participants will:

• Understand the digital oilfield data chain from sensor to decision.
• Be able to design surveillance logic and exception workflows.
• Be able to assess data quality and integration requirements.
• Understand collaboration centre and remote operations practice.
• Be able to evaluate digital investment proposals critically.

• Production engineers
• Well surveillance and optimisation engineers
• Operations engineers and supervisors
• Digital, data and automation staff
• Instrumentation and control engineers
• Asset managers evaluating digital programmes

Upon successful completion of this training course, delegates will be awarded an official Certificate of Completion issued by the Petroleum Engineers Association (PEA), an ISO 9001:2015 certified training organization. The certificate carries 10 Credits and formally records the total learning hours completed.

Each certificate is signed by the Course Facilitator and the CEO of the Petroleum Engineers Association, and serves as verifiable proof of professional training that delegates can present to employers and professional bodies worldwide.