Magnolia Deepwater Development: Striving for Best in Class Drilling Performance
- William R. Reinhardt (ConocoPhillips) | Stephen C. Actis (ConocoPhillips) | Roger N. Williamson (ConocoPhillips) | Luke F. Eaton (ConocoPhillips)
- Document ID
- Society of Petroleum Engineers
- SPE Drilling & Completion
- Publication Date
- December 2006
- Document Type
- Journal Paper
- 268 - 278
- 2006. Society of Petroleum Engineers
- 1.7 Pressure Management, 4.1.5 Processing Equipment, 1.14 Casing and Cementing, 4.5.10 Remotely Operated Vehicles, 1.14.1 Casing Design, 4.2.4 Risers, 1.1 Well Planning, 2.4.3 Sand/Solids Control, 1.6.5 Drilling Time Analysis, 1.12.1 Measurement While Drilling, 7.6.1 Knowledge Management, 2 Well Completion, 5.3.4 Integration of geomechanics in models, 2.2.2 Perforating, 1.10 Drilling Equipment, 1.6.10 Running and Setting Casing, 1.11 Drilling Fluids and Materials, 7.2.3 Decision-making Processes, 1.6.2 Technical Limit Drilling, 1.5 Drill Bits, 1.11.2 Drilling Fluid Selection and Formulation (Chemistry, Properties), 4.5 Offshore Facilities and Subsea Systems, 1.6.1 Drilling Operation Management, 4.1.2 Separation and Treating, 1.3.2 Subsea Wellheads, 3 Production and Well Operations, 1.6.6 Directional Drilling, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 1.4.1 BHA Design, 2.4.6 Frac and Pack, 1.6 Drilling Operations, 1.12.2 Logging While Drilling, 2.4.5 Gravel pack design & evaluation
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ConocoPhillips is developing the Magnolia field with a Tension Leg Platform (TLP) in 4,674 ft of water at Garden Banks (GB) block 783 in the Gulf of Mexico (GOM) (see Fig. 1). The field was discovered in 1999, and appraisal wells were drilled in 2000 and 2001. The well-construction strategy included drilling six additional development wells from a mobile offshore drilling unit (predrilling) before the installation of the TLP. Drilling the new wells consisted of two phases: batch-setting all six wells through 20-in. casing, followed by deepening the wells to a total depth (TD). The wells targeted multiple zones resulting in complex, designer directional wells with 50° to 60° maximum hole angles. This paper examines the application of drilling best practices used to deepen the wells to TD after batch-setting operations were complete (Eaton et al. 2005).
To minimize drilling costs while deepening the wells to TD, project goals were to eliminate trouble time; minimize combined drilling, circulating and tripping time per interval; maximize simultaneous activities; and reduce the number of trips necessary to drill the well. The goal of achieving Best-in-Class performance requires detailed planning, documenting, and implementing of results and lessons learned; effective communications; equipment quality control; and implementation of a team environment with all the companies involved in the drilling program. The complex high-angle wells require employing extended reach best practices to balance on-bottom drilling performance with the ability to effectively clean the hole to enable trouble-free tripping of the bottomhole assembly (BHA), running of casing, and obtaining primary cement jobs.
The best practices discussed in this paper include changes made to improve rotary steerable reliability; simultaneous drilling and under reaming BHA design (Eaton et al. 2001); hole cleaning; and torque and drag monitoring. The paper also discusses activities that reduced the number of required trips and activities conducted out of critical path, such as moving the subsea blowout preventor (BOP) from wellhead to wellhead with an innovative BHA, a BHA to run and retrieve wear bushings, subsea guidebase installation by way of a winch and remote operated vehicle (ROV), off-critical-path makeup of BHA components, and drillstring management.
The Magnolia field will be produced from eight wells with dry trees connected to the TLP. Drilling the three exploration/appraisal wells from the same seabed pattern enabled the wells to be used as TLP production wells. The well-construction strategy included drilling the development wells to TD from a mobile offshore drilling unit (MODU) before the installation of the TLP. The "predrilled?? wells are then completed using a smaller, lighter completion rig installed on the TLP. This reduces the cost of the TLP because of the lighter deck loads requirements vs. those needed for a full sized drilling rig. The predrilled wells also gathered subsurface data before the TLP completion program and accelerated the production by predrilling the wells to TD.
|File Size||1 MB||Number of Pages||11|
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