API 92P 2019 pdf free download

API 92P 2019 pdf free download.Managed Pressure Drilling Operations — Pressurized Mud Cap Drilling with a Subsea Blowout Preventer.
5 Logistics As with any operation, it is essential that logistic considerations be adequately addressed to make sure that all required materials are on hand and in suffcient quantities to ensure that operations are not interrupted. For PMCD operations, this means the sacrifcial fuid, dry material for additional mud mixing (LAM), spares for the RCD and other expendables, etc., are available. 6 Equipment 6.1 Surface Equipment 6.1.1 Distribution/buffer manifold should be considered for the desired operational functionality if surface back- pressure (SBP) technique will be used. A distribution/buffer manifold enables the diversion of fuids into or out of the well. 6.1.2 Sacrifcial fuid treatment upstream of the rig pump suction should be considered for minimizing corrosion. 6.1.3 Suffcient pump capacity to pump sacrifcial fuid down the drill string and LAM in the annulus shall be available. 6.1.4 Suffcient delivery capacity to build and transfer either LAM or sacrifcial fuid shall be available to meet or exceed the pump rate required to go downhole.
6.2.1 General Principles 6.2.1.1 It shall be possible to maintain the current well conditions while changing the RCD element. 6.2.1.2 A sealing device below the RCD (currently annular devices are used) should be considered for use in RCD element replacements. 6.2.1.3 An updated shut-down philosophy covering the MPD riser components shall be established for both planned and unplanned events. 6.2.1.4 The riser shall be protected from overpressure. 6.2.1.5 Riser pressure protection should be provided by PRV designed in accordance with the following standards: — API 14C or ISO 10418; — API 520; — API 521; — IEC 61511–1. Riser loads shall be evaluated with respect to maximum surface pressure. MPD riser components should possess suitable tensile strength, pressure strength, and fatigue life for the operations planned, including riser deployment and recovery, ideally matching or exceeding the existing riser tube/connector strength, whichever is the lesser. Ideally, this arrangement should enable all MPD equipment to be installed in the riser string prior to BOP being latched to the subsea wellhead (refer to API 2RD). Riser fatigue assessment should consider vortex-induced vibration and pressure cycling. 6.2.1.6 Flexible hoses and related fttings should be suitable for anticipated service conditions, harsh environments, currents, thruster forces, maximum anticipated operating pressures, potential collapse pressures, drilling fuids planned for use, and any wellbore fuids or gases that may pass through them when handling infuxes. Applicable standards should be used during design. For example, API 17K, ISO 13628–10, API 17J, API 17B, ISO 13628–11, or ft-for-purpose testing can be used for qualifcation. 6.2.1.7 The system that controls the MPD components should be independent of the BOP control system.
6.2.3 Alternative Riser Isolation Device Considerations The alternative riser isolation device (e.g. MPD annular), is a recommended component in the system used for PMCD operations. In addition to the items in 6.2.2, consider the following when selecting, installing, and using the device. a) Is it acceptable to pull the riser to change the elastomer? b) Is it acceptable to use one of the subsea annulars at the mudline? c) What is the existing functionality available at the rig; i.e. does the rig incorporate a riser gas handler (RGH)? 6.2.4? Riser? Confgurations 6.2.4.1 General There are two main MPD riser component confgurations, classed as follows. a) above tension ring (ATR): denotes that the MPD telescopic joint, RCD housing, MPD annular, and fow return spool (if used) are inserted in the riser string above the riser tensioner load ring. b) below tension ring (BTR): denotes that the RCD housing, MPD annular, and fow return spool are inserted in the riser string below the riser tensioner load ring. There are other confgurations used that involve alternative placement of the required equipment. The following subsections briefy describe some typical equipment layouts, listing points to be aware of during planning and design. These arrangements are discussed from the bottom up, starting from the subsea BOP stack assembly, which is latched to the subsea wellhead