The VisiTrak? reservoir navigation and analysis service lets you see more of your reservoir – up to 100 feet from the wellbore – so you know exactly where you are and where you need to go in order to build a better well. And when you can see 100 feet away, you can:
Land your well more efficiently.
With conventional logging while drilling (LWD) mapping and navigation technology, you can see only about 20 feet away from the wellbore. Because the VisiTrak service can map the reservoir up to 5 times that distance in real time, you don’t need to drill costly pilot holes to confirm the top and bottom of the reservoir. Or worry about coming in too low or too high and having to spend unnecessary time steering back into the reservoir.
Find the sweet spot and stay in it longer.
Finding the sweet spot and staying there means more production and greater return on investment. The advanced navigation technology behind the VisiTrak service lets you identify the optimal producing zone and helps you avoid early exits – keeping you in the sweet spot longer.
Build a better long-term plan.
When you can see 100 feet into the reservoir, you can map approaching beds, boundaries and pay zones so you can design a completion and field management plan that maximizes long-term production potential.
The VisiTrak service is part of Baker Hughes’ complete package of reservoir navigation services that combine formation evaluation technologies, interactive software and experienced reservoir experts that can help maximize your assets.
Applications
- Deepwater；
- Complex, geology with channelized sands；
- Horizontal and deviated wells.
VisiTrak services may eliminate need for pilot wells in wellbore placement
As operators continue to target increasingly complex geological formations in deepwater reservoirs, accurate and efficient horizontal wellbore placement has become essential to productivity. Conventional methods for mapping out wellbore placement involve drilling pilot wells, which can cost millions of dollars to drill. Baker Hughes aims to remove the need for such pilot wells, while also improving recovery, with the VisiTrak Geospatial Navigation and Analysis Service, commercially launched in July 2015. “This represents the combination of two decades developing reservoir navigation,” said Jon Skillings, Product Line Manager, Reservoir Navigation Services, Baker Hughes.
The service is able to map out a full geological interpretation around the wellbore in real time with the help of shallow, deep and extra deep reading sensors that are attached to the rotary steerable-equipped BHA. The sensors are equipped with both omnidirectional – observing 360? around the BHA – and extra deep reading azimuthal resistivity functionality. Together, these capabilities allow the operator to measure the targeted reservoir and detect bed boundaries from up to100 ft away using low-frequency electromagnetic waves, Mr Skillings said.
Data from the sensors is interpreted using a semi-automated inversion algorithm. “The algorithm allows the user to select the most appropriate inversion strategy for each geological scenario by incorporating the operator’s prior geological knowledge about the reservoir structure and properties to define plausible parameter ranges,” he said. Baker Hughes developed VisiTrak specifically for deepwater horizontal drilling in places like the North Sea – offshore Norway, UK and Holland, as well as offshore Brazil and West Africa.. In these places, Mr Skillings pointed out, the costs of missing or drilling straight through the reservoir can be especially high.
VisiTrak Reservoir Navigation and Analysis Service Navigated 2,838 Feet of Pay Sand Without Pilot Hole
Location: Carapebus Reservoir, Offshore Brazil
An operator drilling in the Carapebus reservoir off the shore of Brazil requested that Baker Hughes drill an 8?-in., 3,340-ft (1018-m) horizontal section in the reservoir’s facies 1 sand. The heel of the well was in an area below seismic resolution.
The Carapebus reservoir is a series of gravity flow channel deposits on the continental slope margin of the Campos Basin. The reservoir is subdivided into 3 facies types, with facies 1 being the only productive sand type. The thickness and distribution of the facies 1 sand within the reservoir was poorly known.
The plan was to drill a 12?-in. hole to the top of the Carapebus reservoir and set 9?-in. casing. The well inclination would then be built to land at 90° and maintain position in the target zone before drilling into the lower sand.
Total depth was at the start of a deep channel that cut across the well trajectory. The minimum net sand interval was set at 984 ft (300 m) with a KPI minimum of 1,509 ft (460 m).
Baker Hughes used a logging-while-drilling (LWD) suite of services, including its VisiTrak? geospatial reservoir navigation and analysis service, AziTrak? deep azimuthal resistivity service, and LithoTrak? advanced LWD porosity service, to detect, measure, and visualize the reservoir. Inversion modeling software was also used for realtime, multiple bed boundary interpretation.
Density and gamma ray images from the LithoTrak and AziTrak services also provided real-time dip measurements to help geosteer through the well. Two nearby horizontal offset wells, each targeting separate sands, were used for the prewell modeling.
The data gathered was seamlessly incorporated and the model was adjusted in real-time using the Baker Hughes Reservoir Navigation Services? interactive software in combination with the realtime inversion modeling software.
With the information gathered, Baker Hughes was confident it could steer the well without having to drill a pilot hole. The sand was 33 to 46 ft (10 to 14 m) true vertical thickness at the heel of the well. After crossing the crest into the lower channel, the thickness increased to 33 to 82 ft (10 to 25 m). The well followed the upper surface of the sands at a distance of 7 to 10 ft (2 to 3 m).
When faults and channel margins were crossed, inversion modeling results were used to target the correct reservoir sands. A total net sand length of 2,838 ft (865 m) was drilled, which equates to a 75% net-to-gross.
The use of the Baker Hughes Reservoir Navigation Services in conjunction with the LWD suite of services proved to be a successful combination for drilling in this complex, subseismic environment.
Background and challenges
- Two horizontal offset wells available for pre-well modeling;
- Sand distribution in well landing area was unclear due to seismic interpretation limitations;
- Total planned length of horizontal section was 3,340 ft, with a minimum required net sand of 984.3 ft.
Baker Hughes solution
- VisiTrak reservoir navigation and analysis service;
- AziTrak deep azimuthal resistivity LWD service;
- LithoTrak advanced LWD porosity service;
- Reservoir Navigation Services interactive software’
- Real-time inversion modeling software.
Results
- Drilled horizontal well successfully without a pilot hole;
- Mapped target sand thickness while following the upper surface of the sand;
- Mapped correct reservoir using real-time inversion results after crossing faults;
- Drilled 75% net-to-gross sand along a 3,343.2-ft (1019-m) horizontal section.
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