API RP 1182 pdf free download
API RP 1182 pdf free download.Construction, Operation, and Maintenance of Large Diameter Rural Gas Gathering Lines.
4.3.1.1 Natural Gas Factor 4.3.1.1.1 The rich natural gas factor of 0.73 shall be used in the potential impact radius calculation, unless the operator determines that the use of the lean natural gas factor of 0.69 is justified. 4.3.1.1.2 To justify the use of the lean natural gas factor in a potential impact radius calculation, an operator shall demonstrate that the gross heating value of the gas composition is less than or equal to 1 1 00 Btu/cubic foot. 4.3.1.1.3 If an operator uses the lean natural gas factor in a potential impact radius calculation, appropriate documentation justifying that determination should be kept for the life of the pipeline. 4.3.1.1.4 If the quality of the gas changes from lean to rich gas, requiring a different gas factor, PIR shall be re-calculated for the new composition. 4.3.2 Potential Impact Circle The operator shall determine whether the potential impact circle contains either of the following: — One or more buildings intended for human occupancy; or — One or more other impacted sites. 4.3.2.1 In making a determination under Section 4.3, the potential impact circle extends axially along the length of the pipeline from the outermost edge of the first potential impact circle that contains either a building intended for human occupancy or another impacted site to the outermost edge of the last contiguous potential impact circle that contains either a building intended for human occupancy or another impacted site.6.3.1.5 Remedial Action An operator shall take remedial action to correct any deficiencies indicated by the monitoring performed in accordance with 6.3.1 .4. The remedial actions shall be completed within a timeframe commensurate with the identified threat. 6.3.2 Coating 6.3.2.1 A new metallic pipeline designed for cathodic protection shall have an external protective coating. 6.3.2.2 An operator shall protect the external protective coating from damage in accordance with recognized and generally accepted practices. 6.3.2.3 An operator should take additional precautions when boring or when a pipeline is cased to protect the external protective coating. 6.3.3 Electrical Isolation 6.3.3.1 A buried or submerged metallic pipeline should be electrically isolated where necessary to facilitate the application of corrosion control. 6.3.3.2 A cathodically protected pipeline should be electrically isolated from metallic casings that are part of an underground system where corrosion is a threat, unless other measures are taken to minimize corrosion of the pipeline inside the casing. 6.3.3.3 Inspection and electrical tests should be made to ensure that electrical isolation is adequate.6.3.4 Stray Currents If a pipeline is subjected to stray electrical currents (AC/DC), the operator shall take actions to mitigate any adverse effects on underground metallic structures. 6.4 Internal Corrosion Control If a corrosive gas stream is transported in a buried metallic pipeline, the operator shall take steps to minimize corrosion or demonstrate that the level of corrosivity is acceptable. An operator should conduct monitoring to determine the effectiveness of the steps taken. 6.5 Atmospheric Corrosion Control At least once every three calendar years, not to exceed 39 months, an operator shall inspect a pipeline that is exposed to the atmosphere for evidence of atmospheric corrosion. If atmospheric corrosion is found that could affect the safe operation of the pipeline, the operator shall take appropriate remedial action.API RP 1182 pdf download.
