API RP 53:1997(R2004) pdf download.Recommended Practices for Blowout Prevention Equipment Systems for Drilling Wells
The purpose of these recommended practices is to provide information that can serve as a guide for installation and test- ing of blowout prevention equipment systems on land and marine drilling rigs (barge, platform, bottom-supported, and floating). Blowout prevention equipment systems are com- posed of all systems required to operate the blowout preven- ters (BOPs) under varying rig and well conditions. These systems are: blowout preventers (BOPs), choke and kill lines, choke manifold, hydraulic control system, marine riser, and auxiliary equipment. The primary functions of these systems are to confine well fluids to the wellbore, provide means to add fluid to the wellbore, and allow controlled volumes to be withdrawn from the wellbore. In addition, diverter systems are addressed in this Recommended Practice, though their primary purpose is to safely divert flow rather than to confine fluids to the wellbore. Refer to API Recommended Practice 64 for additional information on diverter systems. Marine ris- ers are not dealt with in detail in this document. Refer to API Recommended Practice 16Q for additional information on marine drilling risers.
It is important to distinguish between the standards for in- the-field control system accumulator capacity established here in Recommended Practice 53 and the design standards established in API Specification 16D. API Specification 16D provides sizing guidelines for designers and manufacturers of control systems. In the fac- tory, it is not possible to exactly simulate the volumetric demands of the control system piping, hoses, fittings, valves, BOPs, etc. On the rig, efficiency losses in the operation of fluid functions result from causes such as friction, hose expansion, control valve interflow as well as heat energy losses. Therefore, the establishment by the manufacturer of the design accumulator capacity provides a safety factor. This safety factor is a margin of additional fluid capacity which is not actually intended to be usable to operate well control functions on the rig. For this reason, the control system design accumulator capacity formulas established in Specification 16D are differ- ent from the demonstrable capacity guidelines provided here in Recommended Practice 53. The original control system manufacturer shall be con- sulted in the event that the field calculations or field testing should indicate insufficient capacity or in the event that the volumetric requirements of equipment being controlled are changed, such as by the modification or changeout of the BOP stack.
API RP 53:1997(R2004) pdf download
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