The value of a permanent gauge is not one measurement but the record. Ten years of continuous bottomhole pressure contains every shut-in the well experienced, each of which is a pressure transient test that cost nothing to acquire. It contains the response to every rate change on neighbouring wells, which is interference data. It shows the exact moment scale began restricting flow or a pump began to fail.

Fibre optic sensing extends this along the well. Distributed temperature sensing gives a temperature profile every few metres, which identifies inflow zones, gas entry through cooling, leaks and injection distribution. Distributed acoustic sensing captures sound along the fibre and is used for flow profiling, fracture monitoring and leak detection. Both produce large data volumes that need processing rather than simple reading.

Reliability is the constraint. Downhole electronics fail, cables get damaged during installation, penetrators leak and a failed gauge cannot usually be replaced without pulling the completion. Installation quality determines survival more than gauge specification, and the economics rest on whether the system survives long enough to deliver the data it was installed for. This course covers the technology, the data and that reliability question honestly.

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

• Describe downhole gauge technologies and their accuracy, resolution and drift characteristics.
• Specify gauges, cables, clamps and penetrators for permanent installation.
• Plan installation practice that maximises system survival.
• Describe distributed temperature and distributed acoustic sensing and their applications.
• Describe downhole flow and phase measurement options.
• Specify data acquisition, transmission, storage and access systems.
• Validate permanent gauge data and correct for drift and gaps.
• Apply permanent pressure data to transient analysis, interference testing and reservoir surveillance.
• Apply monitoring data to artificial lift and flow assurance surveillance.
• Evaluate the reliability and economics of permanent monitoring systems.

Organisations sending participants to this training will:

• Get continuous well data without intervention cost.
• Improve reservoir surveillance and pressure transient analysis coverage.
• Detect well and lift problems earlier through continuous monitoring.
• Improve installation practice and gauge survival rates.
• Base monitoring investment on realistic reliability and value estimates.

Participants will:

• Understand downhole gauge and fibre optic sensing technologies.
• Be able to specify and plan a permanent monitoring installation.
• Be able to validate and analyse continuous downhole data.
• Be able to extract transient tests and interference data from gauge records.
• Be able to evaluate the value case for permanent monitoring.

• Production engineers
• Reservoir engineers
• Well surveillance and optimisation engineers
• Completion engineers
• Instrumentation and data engineers
• Field development engineers

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.