Deepwater-Development Production and Export Options
- Dennis Denney (JPT Senior Technology Editor)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- June 2010
- Document Type
- Journal Paper
- 41 - 42
- 2010. Society of Petroleum Engineers
- 1 in the last 30 days
- 84 since 2007
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This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper SPE 123415, "Deepwater-Development Production and Export Options," by W.D. Hartell, SPE, and J.R. Greenwald, Hess Corporation, prepared for the 2009 SPE Asia Pacific Oil and Gas Conference and Exhibition, Jakarta, 4-6 August.
Deepwater discovery and development activities can be far from existing infra-structure, such as other facilities and pipelines. The choice of production and export options for hydrocarbon liquid and gas is important and is affected by distance to other infrastructure and by water depth, geohazards, reservoir-fluid characteristics, production rates, and reserves. In Southeast Asia, deepwater developments often are hundreds of kilometers from onshore markets, so the development production and export options must be wide to obtain economic and timely choices.
As deepwater developments move into more-remote locations in Southeast Asia, options to develop these “stranded” resources are becoming more challenging. Industry advancements for developing these resources provide multiple options for production and export. Prospective deepwater locations in eastern Indonesia, Papua New Guinea, Philippines, South China Sea, and Australia are gas prone and are long distances from market. Technical and commercial foundations for floating gas production and nonpipeline-export options in Southeast Asia are examined.
Production and Export Options
Given the assumptions of a remote, deepwater hydrocarbon development with hydrocarbon liquids and gas, it is likely that a development scenario would be as follows. Subsea wells would be spread over the field, either as distributed single wells or grouped into drill-center clusters. Production would move from the seabed manifolds in some number of production risers, steel catenary risers, buoyant riser towers, flexible risers, or some combination of these. On the surface of the ocean, there would be a floating production host [i.e., spar, tension-leg platform (TLP), semisubmersible, or a floating production, storage, and offloading (FPSO) vessel].
Conventional gas-export options for remote deepwater locations, such as long-distance gas pipelines requiring compression facilities along the route to markets, are likely to be very expensive. They may be technically too challenging if combined with sea-bed geohazard challenges such as deep trenches, unstable slopes, or areas of seismic activity. These challenges and high costs lead to consideration of floating production options such as processing the gas into more-transportable products.
Gas-Market Options. Compressed Natural Gas (CNG). CNG can be an attractive option (or partial solution) where distance to markets is not too great. It is an attractive option with lower investment needs (i.e., cheaper production facilities, transport vessels, and discharge facilities).
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