Experience and Results with a New Automated MPD System while Drilling and Cementing Liner in an Onshore Depleted Gas Field

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).

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Onshore US MPD Use by an Operator

Montilva

Mota

Billa

2012

All Days

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In the development of onshore gas fields SWEPI LP (Shell) has encountered margins in which the difference between dynamic ECD and static BHP is the difference between lost circulation and influx. The limits imposed by those conflicting conditions create narrow mud weight windows. The reasons for the tight pore pressure and fracture gradient windows in these vertical and horizontal onshore HPHT tight gas environments vary. Some are old fields challenged by depletion. In the case of South Texas, the main problem is losses in the production hole due to depletion. The pressure in different zones is often difficult to predict due to complex geology further complicated by years of commingled production without knowing what each zone has contributed. In some of the new shale plays, like the Haynesville, slim hole well plans are used which have problems with low kick tolerance design and unexpected kicks through fractured intervals. These pose unique well control challenges to minimize non productive time. In all of these wells, there is the high cost associated with losing mud and/or constantly changing mud weights to prevent losses or influxes. To mitigate these potential problems, Shell has recognized the use of the Managed Pressured Drilling (MPD) concept which enables the use of the lowest possible mud weight to drill these challenging wells. By lowering the mud weight and manipulating the annular pressure during drilling, the risk of mud losses and/or quick sudden transitions into over-pressured zones is reduced. There are some direct benefits of drilling with lower mud weight such as higher ROP's, lower stand pipe pressures and lower circulating temperatures. In addition, there are lower ECD's and higher pump rates that improve the hole cleaning. Field trials using a fully-automated MPD solution were performed by Shell in South Texas and North Louisiana Haynesville from late 2010 to mid 2011. This paper describes implementation of a fully automated MPD, small rig foot print system which incorporates a Rig Pump Diverter (RPD) that allows smooth transition from circulating to non-circulating down hole during connection while maintaining continuous rig pump circulation. Results from the field trials will be documented in the paper. We will show the impact of drilling with lower mud weights on well performance. Additionally, a comparison of vertical and horizontal HPHT wells that were drilled conventionally and wells drilled using MPD will be made showing the effects of drilling with lower mud weights on ROP, down hole circulating temperature, ECD, stand pipe pressure and pump rate.

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Experience and Results with a New Automated MPD System while Drilling and Cementing Liner in an Onshore Depleted Gas Field

Cited by 5 publications

References 1 publication

Underbalanced Liner Drilling

Underbalanced Liner Drilling

Next-Generation Managed Pressure Drilling System Enables HP/HT Horizontal Wells in the Haynesville Shale

Onshore US MPD Use by an Operator

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