Innovative Remedial Cementing Solution Provides Annular Isolation in Duyong B-4, Petronas Carigali
- Thomas C. Morris (Schlumberger) | M. Zuki Bidi (Petronas Carigali Sdn. Bhd.) | Youssef A. Elmarsafawy (Schlumberger) | Devan Nair (Schlumberger) | Rifat Said (Schlumberger) | Reha Tugcu (Schlumberger WTA Malaysia S/B) | Jane Ong (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE Drilling & Completion
- Publication Date
- March 2006
- Document Type
- Journal Paper
- 62 - 67
- 2006. Society of Petroleum Engineers
- 2.2.3 Fluid Loss Control, 4.3.1 Hydrates, 1.6 Drilling Operations, 1.14.3 Cement Formulation (Chemistry, Properties), 1.14.4 Cement and Bond Evaluation, 1.6.10 Running and Setting Casing, 4.1.4 Gas Processing, 5.2.1 Phase Behavior and PVT Measurements, 3 Production and Well Operations, 2.2.2 Perforating, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 4.1.3 Dehydration, 5.1.1 Exploration, Development, Structural Geology, 5.6.4 Drillstem/Well Testing, 1.14 Casing and Cementing, 4.5 Offshore Facilities and Subsea Systems, 4.1.2 Separation and Treating, 4.1.5 Processing Equipment
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Whether a cement-squeeze operation results in an annular seal depends heavily on how far the cement can penetrate and disperse in the fine channels of a partially cemented annulus. In many cases, a conventional- or microfine-cement slurry will dehydrate and bridge off before it can achieve its objectives (Nelson et al. 1990). This paper describes the use of an engineered, optimized slurry for a squeeze operation in the Duyong B-4 well, which had a perforated zone that demonstrated a low rate of seawater injectivity. This paper also presents the slurry design and properties, execution procedure, and prejob and post-job log evaluations.
After several years of production, gas bubbles appeared in various locations throughout the Duyong field. Shallow seismic readings showed gas charging in several shallow gas layers throughout the Duyong field. Several wells were investigated as possible contributors to the charging of the shallow sandstone layers, and Duyong B-4 was selected as a probable contributor. Duyong B-4 is a gas well that was completed in November 1983 with four producing zones. In September 2003, this well was selected as a test well to evaluate the cement quality behind the casing. Both cement-bond logs and ultrasonic-imaging logs showed gas and fluid channels behind the casing. An optimized cement slurry (OCS) was engineered and tested in the laboratory under well conditions. Results showed excellent penetration in narrow gaps, optimum fluid-loss control, and low rheology, both at surface and downhole conditions.
The slurry was used in the squeeze operation; post-job logs demonstrated the success of the treatment. The slurry penetrated the narrow gaps without dehydrating, and good mechanical properties were achieved in short setting times (Moulin et al. 1997). These properties are especially important in gas-producing wells, and they met all the objectives set forth by the client.
The Duyong gas field is located offshore, approximately 220 km (136 mi) east of peninsular Malaysia. The first gas from the field was produced in 1984. The complex comprises three wellhead platforms (DDP A, DDP-B, and DDP-C), a central processing platform (CPP), a gas-compression platform (GCP), a flare tripod (FT), and a living-quarters platform (LQP).
The platforms that make up the main complex—the LQP, CPP, GCP, and DDP-B platform—are connected by a bridge. The FT is located north of the CPP and is connected by a bridge to the CPP. DDP-A and DDP-C are remote to the CPP complex. Each wellhead platform has nine well slots. Four wells were completed on DDP-A, six wells on DDP-C, and six wells on DDP-B. The fluids from the wells are piped to the CPP. Separation of gas condensate and produced water, dehydration of the gas, and metering and disposal of the produced water take place at the CPP. Gas is then piped to shore through the peninsular Malaysia gas system.
The Duyong shallow-gas second-mitigation studies indicated that Well B-4 had fair-to-poor cement bond behind the 9??-in. casing. There are no data on the cement quality behind the 13?-in. casing. Furthermore, casing to casing pressure was observed in the annuli of CCP1 between the 9?? and 13?-in. casing and in the annuli of CCP2 between the 13?- and 20-in. casing. The observed pressures are believed to originate from gas channeling behind the casing(s).
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