Design and field methods of diagnosing the condition of oil and gas pipeline systems

Currently there is a need to quantify the physical condition of underground pipelines with a view to their certification and planning of major repair costs. Part of field techniques is outdated and requires revision. For example, guidelines for corrosion testing include: a) a quality assessment of insulation coating of the pipeline at selected points of the network; b) prediction of the corrosion process. The author makes measurements necessary for the evaluation of the corrosion process and recommended for pipelines as no other valuation techniques are not recommended for universal application. In addition to direct costs the following negative processes were identified: 1. Excavator breaks the integrity of the insulating material with a bucket at the opening of the pipeline. 2. Carried out insulation of exposed sections of the new sticky tape, or fresh bitumen will lead to the fact that the pipe in the pit will have galvanic heterogeneity, the anode of which is the border between old and new insulation, and a cathode, the rest of the old pipeline with cracks in the insulation. This will result in a pipe network of hundreds of new corrosion micropar. The article deals with the use of existing methods of assessing the quality of anti-corrosion coatings in the calculation of capital repair costs. The author demonstrates their advantages and disadvantages. It is proposed to use the device to tie-in to existing pipeline, which has a higher functionality in comparison with other types of devices due to the possibility of tie-in pipelines of different diameter.