Zonal Isolation and Evaluation for Cemented Horizontal Liners

Gai, H.; Summers, Tim; Cocking, D.A.; Greaves, Celia

doi:10.2118/29981-pa

Cited by 14 publications

(3 citation statements)

References 4 publications

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“…A channel can only be confirmed retrospectively with several methods, but may not be detected as positive prediction with current technology (Gai et al, 1996). Contaminated cement capable of forming a hydraulic seal can be shown as poor cement bond on both cement bond log (CBL) and ultrasonic tool logs (Hayman et al, 1991).…”

Section: Field Case Study 3: Cement Diagnosismentioning

confidence: 99%

Using Microseismic Monitoring as a Real Time Completions Diagnostic Tool in Unconventional Reservoirs: Field Case Studies

Ajayi

Walker

Sink

et al. 2011

SPE Eastern Regional Meeting

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Horizontal wells drilled in unconventional gas reservoirs are often completed by combining multiple perforation clusters in a hydraulic fracture treatment stage. Each treatment stage is typically prevented from communicating by using an isolation plug. It is a challenge to design a limited entry completion that comprehensively ensures that all perforation clusters are equally stimulated within a treatment stage (Miller et al, 2011, Mcdaniel et al, 1999. Slippage or failure of isolation plugs have also been known to occur during treatment execution and in many cases, these failures are discovered only after the well stimulation has been completed. This paper presents three case studies in the Marcellus Shale where real-time microseismic Hydraulic Fracture Monitoring (HFM) was used to evaluate the behavior and development of the induced fracture and a need for the corrective intervention was observed. In one of the cases, an innovative corrective action was implemented and microseismic results show that the intervention was successful.This study shows how real-time microseismic monitoring can been used for not only evaluating fracture geometry and azimuth but can also be used as a diagnostic tool for observing operational failures in completion tools as well as making real-time changes to completion design in order to improve completion efficiency. Some of the potential failures that may be diagnosed using HFM analyzed in this study include loss of isolation between hydraulic fracture stages, breach in casing integrity, poor cement bond in annulus and confirmation of plug ball seating.The first case study describes a hydraulic fracture treatment where the real-time HFM interpretation was useful in identifying a failure in the isolation plug between completion stages. This observation during the treatment execution was later confirmed by tagging the depth of the plug during coiled tubing operations. A production log was also run in the well and showed limited production contribution from the stage with the plug failure. The other two case studies address the use of real-time HFM interpretation to identify undesired fracture growth into an already stimulated region. Subsequent intervention by using an isolation plug between perforation clusters as a means of diversion was implemented in one of the cases.These examples clearly show how real-time microseismic monitoring can be used to adapt conventional completion designs to the dynamic nature of completion operations in the field. The paper also highlights the innovative use of an isolation plug as a diversion mechanism during fracture treatment.

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Section: Field Case Study 3: Cement Diagnosismentioning

confidence: 99%

Using Microseismic Monitoring as a Real Time Completions Diagnostic Tool in Unconventional Reservoirs: Field Case Studies

Ajayi

Walker

Sink

et al. 2011

SPE Eastern Regional Meeting

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“…casing connection threads, because cement bond quality is significantly enhanced by rotating the casing string during cementation [9][10][11] . This requires the choice of a thread design specified to withstand the anticipated torque figures of up to 2050 daNm (15,000 ft-lbs).…”

Section: Drill-in Fluidmentioning

confidence: 99%

Rapid Pressure Support for Champion SE Reservoirs by Multi-Layer Fractured Water Injection

Sommerauer

Zerbst

2006

SPE Asia Pacific Oil &Amp; Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe Champion field is a large oil field offshore Negara Brunei Darussalam. This paper discusses thefor us -novel application of multi-layer fractured water injection into three shallow reservoirs in the Champion Southeast field (CPSE). The project is part of a larger secondary recovery implementation scheme and future efforts to increase economic oil production and ultimate recovery in the whole Champion field.The main boundary condition for the rapid water injection project is the use of existing infrastructure with the exception of three new water pipelines and nine new wells. This paper describes the following:• Reservoir setting and production history.• Water injection philosophy.• Design considerations for fractured water injection including: o Pressure requirement to design for fractured water injection. o Simulation of fracture growth and containment and resulting conclusions. • Design considerations for the multi-layer fractured water injector wells including: o Selected Drilling Aspects (well trajectory, drill-in fluid, formation evaluation, casing scheme). o Completion Design Considerations (clean-out, perforating, sand control, selectivity, "smartness", other). o Material selection. One of the main conclusions is that fracture growth and containment is not a major issue in soft, high-permeable formations. The main challenge is in drilling the sometimes-demanding well trajectories and running the ("smart") completions in these wells with small tolerances.

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“…Special attention was paid to the selection of the reservoirliner connection threads because cement-bond quality is enhanced significantly by rotating the casing string during cementation (Landrum et al 1985; Buchan and Little 1988;Gai et al 1996). This required the choice of a thread design specified to withstand recorded torque figures up to 4200 and 7600 da N•m (31,000 and 56,000 ft-lbf ) for 7 in.…”

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confidence: 99%