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The Goliat field, operated by Eni Norge AS, has two separate sandstone reservoirs planned for development—the late Triassic/Jurassic Realgrunnen subgroup at approximately 3,609 ft (1,100 m) mean sea level (MSL), and the Middle Triassic Kobbe formation at approximate 5,906 ft (1,800 m) MSL. The Goliat field is the first oil-producing field in the Barents Sea.

The operator selected two gas injectors as the optimum production solution. Before the Goliat development, there were no horizontal wells in the Kobbe formation.

Although the field’s geometry requires horizontal production wells for effective drainage, its structure is relatively steep and prone to faults. Because of this, all compartments must be penetrated to ensure optimal gas injection to enhance oil recovery, but the wellbore’s trajectory was restricted to 1.5° dogleg severity after the landing.

To map the reservoir’s boundaries within 98 ft (30 m) of the wellbore, the operator used the VisiTrak™ reservoir navigation and analysis service and AziTrak™ deep azimuthal resistivity service from Baker Hughes, a GE company (BHGE). Multilayered response modeling using BHGE's inversion modeling software was also used to provide high-quality, real-time structural information and reservoir thickness mapping.

Interactive software from BHGE's Reservoir Navigation Services™, in conjunction with the inversion modeling software, delivered an enhanced understanding of the reservoir, enabling the operator to navigate within the pay zone.

Real-time inversion interpretations were also enhanced by deployment of threedimensional (3D) visualization techniques to understand differences with the geomodel. Interpreted formation tops were delivered to the operator in real time to correlate and cross-check with input seismic horizons.

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Challenges & Results
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Challenges

  • First oil-producing field in the Barents Sea • Complex structural environment • Wellbore trajectory restricted to 1.5° dogleg severity
  • Complex structural environment
  • Wellbore trajectory restricted to 1.5° dogleg severity

Results

  • Gathered all measurements in real time using LWD services
  • Provided all interpretations in 3D environment
  • Mapped reservoir boundaries within 98 ft of the wellbore
  • Drilled 3,281 ft with average ROP of 92 ft/hr
  • Provided real-time inversion answers