Managing pressure cycling on connections during drilling operations remains the greatest challenge for Managed Pressure Drilling (MPD) operators today. During conventional MPD operations, systems typically employ back pressure pumps to compensate for well back pressure across the well head. These conventional systems require a delicate control on connections between the driller managing rig pumps and the MPD operator managing back pressure pumps. This paper describes implementation of a fully automated MPD system which incorporates a Rig Pump Diverter (RPD) that allows smooth transition from circulating to non-circulating down hole during connections while maintaining continuous rig pump circulation. The RPD system allows flow to be diverted from the stand pipe to the choke manifold, enabling accurate control of the bottomhole pressure (BHP) for controlled transition from drilling mode to connection mode. This paper will further describe the time savings and enhanced drill crew workflow associated with the use of the RPD system. The paper describes the MPD implementation process, which included front-end engineering and design, HAZID/HAZOP (pre-job process of identification and management of potential hazards for operations), flow loop testing, in-house simulation, on-site drill crew training and will delineate the benefits of using the new system such as controlling annulus pressure during drilling operations. Additionally, results of field trials performed in High Pressure / High Temperature (HPHT) horizontal wells in the Haynesville Shale will be described. We will show in the paper how this system operates on a small foot print while making the interaction between drilling crews and MPD crews highly effective. We will also demonstrate that the new MPD system provides better control managing pressure cycling, gas expansion and/or influx to the system, enabling effective drilling for better rate of penetration (ROP).

The use of managed pressure drilling (MPD) during drilling operations has proven to be an effective solution for controlling equivalent circulation density (ECD); however, making a drillpipe connection with MPD is more challenging than with conventional drilling. The current methods for making a connection during MPD rely on large, high-maintenance equipment to provide a sufficient fluid supply to maintain the MPD equipment within an operable range. This equipment is both expensive and difficult to use to control ECD efficiently. A new method of smoothly diverting rig pump flow during connections from the stand pipe to the MPD pressure control equipment at the annulus uses a valve manifold with an on-board choke. In addition to eliminating more expensive solutions, this method will improve pressure control and increase the operating range of MPD to provide higher pressures during connections and greater drilling flow rates. Reliability is increased by a reduction in complexity when using this method, because most rigs have multiple pumps available for redundancy. Field trials using a fully automated MPD solution were performed by a major operator in South Texas between late 2010 and early 2011. This paper uses real data based on flow testing and actual field experience to demonstrate that implementing the rig pump diverter method with standard MPD operations effectively controlled the desired annulus pressure during connections. By replacing current methods of making a drillpipe connection, this solution will reduce the overall cost of MPD, making the total MPD solution more feasible for small wells.

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