Fields located in the southeastern area of the Neuquén Province of Argentina are widely recognized for their high formation pressures and related influxes while drilling the production section. Some of the challenges encountered when drilling using conventional techniques include kicks, losses, wellbore instability, and formation damage. They are also known for challenging cementing operations. These wellbore construction challenges can significantly impact non-productive time (NPT). Managed pressure cementing (MPC) has been implemented for recent wells after the target is achieved with managed pressure casing drilling (MPCD). This application enables the implementation of controlled bottomhole pressure (BHP) while cementing, without killing the well. Surface backpressure (SBP) is applied in accordance with the cementing pumping schedule, taking into account varying pump flow rates and fluid densities. In wells in which MPC was implemented, SBP was continuously applied to maintain the target equivalent circulating density (ECD) required for the cementing operation, avoiding expansion and gas migration. This paper describes the implementation, results, and behavior of the well while performing MPC. MPCD and MPC techniques have proven to be an effective combination to help optimize drilling time, improve bottomhole conditions, and reduce cementing costs. This paper includes lessons learned and recommendations to help enhance the implementation of these techniques and optimize the overall well construction phase to improve the performance of future wells.
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 Neuquén basin is located in the Neuquén province in Argentina and comprises the Loma La Lata, Bajo Añelo, and Orejano fields (Fig. 1). The target formations in this project are the Quintuco and Vaca Muerta, which are composed of limestones and marlstones, respectively. Formation pressures range from 1.25 g/cm3 to 1.75 g/cm3 in the Quintuco and up to 2.20 g/cm3 in the Vaca Muerta. Abnormal pressure gradients have been encountered at relatively shallow depths. These characteristics present several challenges when using conventional techniques to drill through these formations, including kicks, fluid losses and associated formation damage, and wellbore instability in the marlstones, all resulting in increased nonproductive time (NPT). The implementation of underbalanced (UBD) and managed-pressure drilling (MPD) techniques has enabled safe production of the hydrocarbon reserves in the Neuquén basin fields. These techniques allow for the immediate adjustment of bottomhole pressure (BHP) when a change in the formation pressure is detected by increasing or decreasing the applied surface-back pressure (SBP) and safely controlling hydrocarbon production to the desired volume at surface. A pressurized closed-loop system, which includes a rotating control device (RCD), choke manifold, 3-phase separation system, and data-acquisition system, enables precise control of bottomhole pressure. Fourteen wells have been drilled in the Neuquén basin, using UBD and MPD techniques. This paper describes the implementation of these techniques when drilling the 8-½-in. and 6-1/8-in. sections, along with results, including the evaluation of reservoir potential while drilling, estimation of formation pressures, minimizing formation damage, as lower-density drilling fluids are being used, reduction of NPT, and being able to safely reach the planned depth. Field data is used to illustrate the challenges encountered and results obtained. Lessons learned and how the drilling process has been optimized are also discussed.
As more complex and challenging wells are being drilled along with the use of new technologies, well control remains a critical operation that requires personnel not only with the right skills set but also to be able to communicate and manage the operation during these stressful situations. This paper will focus on describing the steps taken before, during and after drilling crews have participated in the well control training; it will also highlight the integration of people skills in the schedule and what results, advantages have been observed/obtained by operators and drilling contractors. The use of advanced drilling simulators provides a new environment where drilling crews can not only be trained in how to react and implement the well control procedures, but also allows the implementation of new technologies such as Managed Pressure Drilling (MPD) in highly sensitive environments such as deep water; it provides a safe environment where the drilling team/crew can evaluate these new technologies, and it also facilitates the familiarization with the tools, operational procedures, and communication protocols. While the Drill the Well on Paper exercises provide an opportunity to get the drilling team together and get more familiar with the drilling plan, high end drilling simulators offer a more realistic platform to illustrate the main challenges that crews could face when drilling wells, providing a hands-on learning environment where skills and procedures can be assessed for normal operations as well as during well control scenarios.
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