Offshore Production-2014

Shallow-water offshore production began before 1900 and continues to be important. Technology to maximize economic production from shallow-water fields can be adapted from onshore or deepwater technologies.

Shallow-water offshore production began before 1900 and continues to be important today. Technology to maximize economic production from shallow-water fields can be adapted from onshore or deepwater technologies. Improvements in monitoring-system capabilities (and costs) are direct contributors to optimizing well and facilities operations. Several case studies illustrate the benefits of applying existing technology to increase production in mature operations.

The first case study is of a gas/condensate field. Typical liquid-handling strategies were first applied to mitigate production decline, including converting the test separator to a low-pressure separator. Regular well testing is required for allocation and reservoir management. Previously, low-pressure wells were shut in during the well tests, resulting in production losses. Clamp-on sonar meters allow well testing every 2 months without shutting in production. Data from the sonar metering and other production-surveillance techniques have been used to optimize well cycling.

The second case study describes implementation of through-tubing technology for sand control at a normally unmanned platform. The platform is located in shallow water with onerous sea states. Significant sand production began from an unconsolidated oil zone when the original gas well was converted to commingled production. This paper describes the selection and installation of through-tubing sand control and subsequent selection and installation of through-tubing gas lift. Critical success factors for well rejuvenation at this marginal field include managing marine issues and crane limits.

The last case study discusses installation of a downhole electric heater in an offshore heavy-oil well. Heating heavy-oil reservoirs is uncommon offshore. This successful heater application uses a three-phase system with a cold section to protect the electrical submersible pump (ESP) used to lift the oil. Distributed-temperature sensing monitors temperature profiles in the well. Cable connections—power for the heater and the ESP—are critical for successful operation.

This Month's Technical Papers

Sonar Metering Optimizes Production in Liquid-Loading-Prone Gas Wells

Implementation of Through-Tubing Technology in a Challenging Offshore Environment

Saudi Arabia's Manifa Offshore Field Development: The Role of Technology

Recommended Additional Reading

IPTC 16858 Downhole Electrical Heating for Heavy-Oil Enhanced Recovery: A Successful Application in Offshore Congo by F. Bottazzi, Eni, et al.

OTC 23948 Full-Scale Testing of Distributed-Temperature Sensing in Flexible Risers and Flowlines by Nick Weppenaar, NOV Flexibles, et al.

OTC 23968 Large-Diameter-Riser Laboratory Gas Lift Tests by G. Zabaras, Shell, et al.

Sally A. Thomas, SPE, is a principal engineer in production technology at ConocoPhillips. She holds BS and MChE degrees from Oklahoma State University in chemical engineering. Thomas’ entire career has been with Conoco and ConocoPhillips. Early responsibilities focused on produced water; within the research-and-development organization, she conducted process-development and field-demonstration studies for produced-water recycling and enhanced-oil-recovery projects. After Thomas transferred to process engineering, she developed expertise in process and hydraulic simulation both for ongoing-operations optimization and for new projects. Although mostly stationed in the US, Thomas has had international assignments in the UAE, the UK, and Venezuela. She has served in SPE local-section offices; on regional-meetings organizing committees; as a technical-paper reviewer; as chairperson of the SPE Books Committee; and as a member of the SPE Projects, Facilities, and Construction Advisory Committee and the JPT Editorial Committee.