Cathodic protection (CP) systems are often a vital component of integrity management programs for oil sands facilities. The electrical components of these systems must be designed and installed in accordance with regional electrical codes such as the Canadian Electrical Code (CEC) or the National Electrical Code (NEC). The CEC and NEC include limited direction on the electrical requirements for CP systems. This paper examines installations of typical CP components and suggests ways in which the CEC and NEC can be interpreted. It is demonstrated that interpretation of electrical requirements for CP systems can be difficult. To help improve compliance and understanding future revisions of these codes should provide additional guidance for the design and installation of CP systems.

Integrity of materials in Oil & Gas production wells is critical to meet the objectives of design and the lifecycle performance of wells. This is significant value both in economic terms and health safety and environment. Subsurface uncertainties Aging fields EOR activities and also the quality of procured equipment add to the difficulties in preventing equipment failures in wells. Failures that are especially unforeseen or unanticipated provide crucial feedback to operators and lessons to be learnt. It is imperative for operators to learn improve processes and avoid recurrence of failures.Petroleum Development Oman (PDO) as a large operator with more than 10000 wells has gained important experience and lessons from many such failures. This has contributed significantly to improve the company standards material selection reset the operating envelope and procedures enhance surveillance and improve upon quality assurance and control of new equipment.This paper is a compilation of some of the important lessons learnt from such incidents in the recent past. It discusses the operational experience and learning from different subsurface materials from CS to nickel alloys used in different components such as casing tubing packers and X-trees. 

The demand for high temperature (≤150⁰C) protective coating systems for offshore service has proliferated due to the increase in high temperature pipelines developments in Asia Pacific and Gulf of Mexico regions. Three-layer Polypropylene and multi-layer coating systems are typically used as anti-corrosion coatings for offshore pipelines as they are capable of withstanding operating temperatures as high as 150⁰C and they are resistance to water and mechanical damage. Recently there is an increasing interest in using standalone fusion bonded epoxy coatings single or dual-layer systems for high temperature offshore services. However there is insufficient data available to determine the fitness of purpose for offshore HT environments. Different HT FBE were evaluated and this presentation discusses the performance of coating systems subjected to simulated service testing. In addition test results obtained from a 2-year thermal ageing programunder nitrogen environment will be reviewed and compared between standalone HT FBE and 3LPP coating systems. A qualification protocol will be introduced for HT coating systems for offshore pipelines.