Summary
The Cannonball field is a one-trillion cubic ft gas-condensate development
in offshore Trinidad producing at an initial rate in excess of 800 MMcf/D from
three wells. The completion design selected was 7⅝-in. production tubing with
an openhole gravel pack (OHGP). The initial well (CAN01) has produced at an
initial rate of 320 MMcf/D. The calculated deliverability of this well is 415
MMcf/D. This paper discusses the completion basis of design, detailed
engineering assurance of the design, qualification of critical engineered
equipment, and actual results.
Introduction
Trinidad’s gas production has increased dramatically over the past 10 years.
In 1996, local gas production exceeded oil production for the first time as the
twin island Caribbean state of Trinidad and Tobago moved from a predominantly
oil-producing country to a major gas producer. The gas growth has been driven
by an increase in local demand and construction of a liquefied natural gas
(LNG) infrastructure, which now includes four trains. The company’s share of
the gas supply to the local market has grown from less than 350 MMcf/D in 1994
to over 2 Bcf/D by mid 2007 with production coming predominantly from several
prolific gas fields located off Trinidad’s east coast (Fig. 1).
The Cannonball field is located approximately 35 miles off the southeast
coast of Trinidad in 240 ft of water (Fig. 1). The discovery well, Ironhorse-1
ST1, was drilled in 2002. In 2005, a minimal structure (nine-slot, four-pile)
production platform was installed, and three development wells were drilled and
completed with a jackup-cantilever drilling rig. Initial production commenced
on 12 March 2006 following pipeline hookup and commissioning. The Cannonball
field was brought on production at a sustained rate in excess of 800
MMcf/D.
"Trinidad’s First 500 MMcf/D Well: Fact or Fiction?" (Kronnah et al. 2003)
discussed the Ironhorse discovery well and presented the engineering challenge
of an ultrabore completion (9⅝-in. production tubing). The right scoping
process discussed in this paper presents the various tubing sizes evaluated and
articulates the decision to select 7⅝-in. production tubing.
© 2009. Society of Petroleum Engineers
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History
- Original manuscript received:
2 August 2007
- Meeting paper published:
11 November 2007
- Revised manuscript received:
22 July 2008
- Manuscript approved:
14 August 2008
- Published online:
27 July 2009
- Version of record:
23 December 2009
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