Frac packing is a completion technique that merges two distinct processes-hydraulic fracturing and gravel packing. The main challenge of a frac-pack completion is the successful creation of high-conductivity fractures with the tip-screenout (TSO) technique and the placement of proppant within those fractures and in the annulus between the screen and wellbore wall. This is further compounded by having to do so in an ultra high-permeability environment, in which high fluid-leakoff rates are evident.From 1997 to 2006, job data from more than 600 frac-packing operations, representing an estimated 5% of the worldwide total, have been compiled into a database. This paper reviews well information and key frac-packing parameters. Also summarized are engineering implementations and challenges, best practices, and lessons learned. Essential frac-pack design parameters that were attained from the step-rate test (SRT) and minifrac test are evaluated. These include bottomhole pressure, rock-closure time, and fracturing-fluid efficiency. Downhole pressure and temperature are also discussed because of their importance to the post-completion efficiency evaluation and fracturing-fluid-optimization phase.Worldwide case histories are provided that demonstrate how to both deploy different frac-packing systems and pack the wellbore during extreme conditions with improved packing efficiency and a higher chance of success. Frac-Packing Downhole Tools and ProcedureDeepwater completions have constantly challenged placement design. Pumping rates have been increased to handle longer treatment intervals or to maximize proppant placement. Therefore,
Frac-packing is a completion technique that merges two distinct processes: Hydraulic fracturing and gravel packing. The main challenge of a frac-pack completion is the successful creation of high conductivity fractures using the tip-screen out technique and placement of proppant within those fractures and the annulus between the screen and wellbore. This is further compounded by having to do so in an ultra high permeability environment, where high fluid leak-off rates are evident. Since 1997, job data from more than 600 frac-packing operations worldwide have been compiled into a database. This paper reviews well information and key frac-packing parameters. Also summarized are engineering implementations and challenges, best practices, and lessons learned. Essential frac-pack design parameters attained from the step-rate-test (SRT) and mini-frac test are evaluated. These include bottom hole pressure, rock closure time and fracturing fluid efficiency. Down hole pressure and temperature are also discussed because of their importance to the post completion efficiency evaluation and fracturing fluid optimization phase. Worldwide case histories are provided demonstrating how to deploy different frac-packing systems and pack the wellbore under extreme conditions with improved packing efficiency and a higher chance of success.
The development activities of CABGOC Block 0 pose various challenges to completion design. Multiple types of reservoirs are encountered, while it is also critical ensuring field development remains economic. Completion standardization has been an important tool to maximize operational efficiency and reduce costs of installation. Nonetheless, given the variety of reservoir types found in the area of operation, few completion types are required to solve most of the cases. Despite of having successfully implemented completion standards in several types of reservoirs, there was a gap on the type of completion to efficiently drain multilayered fine particle reservoirs with sanding tendencies. These field characteristics make standard completion techniques difficult to deploy, therefore a novel conformable sand screen solution was selected for a field trial. This paper describes the plan, preparation, execution, and the results of the conformable sand screen deployment in CABGOC's N'Singa field. Furthermore, it demonstrates how effective the conformable sand control technology can be established for a multi zone open hole type of reservoir. Integral zonal isolation and flow control of various zones provided flexibility in production management for a four well campaign. The Shape Memory Polymer (SMP) conformable sand screen technology was key to produce sand free from the fine particle sands in this marginal field in Cabinda Province offshore Angola. Unlike the conventional sand control technique, the conformable sand management system selected for this field trial leverages a unique SMP material that expands downhole in the presence of an activation fluid and conforms to the borehole wall. Compatibility and expansion tests were conducted in the planning stage to validate screen conformance with selected completion fluids. Tests were also used to define deployment procedures and optimal fluids management practices for the completion operation. Installation was successful on all four wells as per plan. All equipment and fluids were managed and operated efficiently with flawless execution. The wells were brought to production and the results confirmed the effectiveness of the technology in terms of sand retention, and completion efficiency during production. The project was concluded with significant reduction in rig time, personnel requirement, fluid management, and pumping operations. This allowed for selective production of reservoir that would not have been possible with standard techniques. Additionally, the obtained results facilitated the decision to implement conformable sand screens as standard completion design for other fields in the reservoir with similar challenges as those observed in N'Singa.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractFor a number of years, the exploration and production industry has sought to prove the feasibility of monobore expandable liner extensions as an advantageous alternative to conventional casing designs. Included as part of the initial casing design, the goal of an expandable monobore liner extension is to enable the operator to drill deeper exploration and production wells with larger hole sizes at the reservoir. As a contingency plan, the goal is to enable the operator to isolate zones that contain reactive shales, sub-salt environments, low fracture gradient formations or other drilling situations without having to reduce the casing and subsequent drilled hole size into the reservoir. A one-trip, top-down expansion system was developed and tested to prove the feasibility of the expandable monobore liner extension concept, including the ability to provide an optimized, cost-effective casing configuration without reducing drilled hole size. During the development process, the need for expandable open-hole packers or optional cementation of the liner was identified and addressed. This paper details the development process for the expandable monobore liner extension system, including testing and the resulting commercial field deployment in an operator well to qualify the technology. This paper will demonstrate the challenges faced during various planning and execution stages and explain how those challenges were met, specifically in the following areas:• Pre-planning wellbore design options and considerations • Monobore liner extension selection, one-trip system reliability • System qualification • Zonal isolation requirements • Field installation considerations • Expansion process • Safety and environmental impact • Post deployment results
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