Advanced Production Operations Support Applying Dynamic Simulation Techniques – Blacktip Gas Field in Bonaparte Basin, Australia By R. Yokote, T. Yamada (currently with INPEX Corp.), J. Derrij, and G. Maniscalco, Eni Australia, and J.C. Mantecon, SPT Group (currently with Chevron ETC), 1 Oct 2014

SPE-171467

This paper describes the work flow adopted by Eni Australia to support Blacktip daily production operations. The Blacktip gas field is located offshore in the southern Bonaparte Basin, Australia. 

Eni Australia is the operator for the Blacktip gas field and holds 100 per cent (%) working interest. Production from the Blacktip gas field started in September 2009 and has been the primary source of gas for Darwin, Northern Territory. The Blacktip gas project consists of a normally unmanned Wellhead Platform (WHP) at a water depth of 50 m, a 110 km offshore Gas Export Pipeline (GEP) and the onshore Yelcherr Gas Plant (YGP). Two deviated production wells were drilled and completed on the WHP in September 2009. Well intervention was carried out on the WHP to shut off a lower production zone and perforate the main production zone in June 2013. 

Untreated gas from the wells is directly sent to the YGP via the GEP, without offshore processing. The gas is treated at the YGP to meet the customer’s specifications and it is sent to Darwin via an onshore gas transmission pipeline operated by a third party. Condensate is processed and stored at the YGP, and offloaded via a 10 km offshore offloading line. 

Multiphase flow numerical transient simulation (dynamic simulation) techniques have been used to establish the work flow to support daily production operations. Three fit for purpose models have been constructed in order to fulfil this task in a timely manner. They are the well(s) model, the GEP model and the offloading line model. History matching of the GEP model has been routinely conducted to monitor pipeline performance and to provide the operations team with relevant information such as liquid volume in the GEP, slug prediction, etc. The condensate offloading line model was used to develop operational guidelines for the first offloading operations conducted in July 2010. In due course, dynamic simulations were applied to support well operations using well models. Regular history matching has been conducted to validate the models and monitor well performance. The well model was also used to establish a sound and safe operations plan for the well intervention campaign, to change the production zone. The application of dynamic simulation is now an integral part of daily production operations for the Blacktip gas field.