The new Roxar subsea Singlephase meter measures both absolute and differential pressures across a venturi, eliminating the problems associated with traditional DP cell measurement. (Image courtesy of Roxar)

Two subsea measurement tools launched

Roxar ASA now offers two new products designed to measure the mass flow rates of fluids or gas in subsea production and injection wells. The addition of the Roxar subsea Singlephase meter (SPM) and the Roxar subsea Singlephase sensor (SPS) to the Roxar portfolio marks the first release of new measurement technology following the merger of Roxar ASA and CorrOcean ASA in July 2007.

The SPM measures both absolute and differential pressures across a venturi, eliminating the problems associated with traditional DP cell measurement. For subsea operators, this provides a broad range of advantages, such as high accuracy, proven reliability, extreme pressure tolerance, and simple subsea installation.

The SPS was developed as an alternative to venturi meters. Based on Roxar’s Force technology, the subsea SPS measures the deflection of an intrusive probe caused by the flowing media. The measurement output from the subsea SPS is intended to enhance or replace traditional calculations based on choke settings. www.roxar.com

Automated downlinking addresses human error

National Oilwell Varco M/D Totco’s DrillLink automated downlinking enables drillers to save time and lower operating costs, according to the company. The system responds to human error, which is widely reported as the top source of delays and drilling inaccuracies on rigs. DrillLink generates command sequences for downlinking to rotary steerable and other downhole tools. Using the rig’s own control system to regulate mud pumps’ speed, DrillLink digitizes and modifies a driller’s throttle signals to send these precise downlinking commands.

Fast downlinking saves time because code in the downhole tool can be modified to recognize shorter duration pulses. In addition, the automated downlinking reduces the always costly opportunity for human error just as repeatable downlinking similarly improves downlinking accuracy since the right code is consistently sent using PLC precision. And, with DrillLink using a percentage of the driller’s throttle setting, no calibration is necessary.

This downlinking automation eliminates the need for a directional driller to continually monitor a stopwatch while giving instructions to the driller. In contrast, pulldown software menus ensure that the right instruction for each tool is always loaded. Faster downlinking enables more course corrections without regard for rig time.

System components include DrillLink console, driller’s control box, service company laptop, and terminal strip.

DrillLink installation requires only a few hours, and, after install, the system can be rigged up in minutes. www.nov.com

Wellsite multiphase fluid sampling and analysis service introduced

Schlumberger has released its new PhaseSampler wellsite multiphase fluid sampling and analysis service.

The compact system operates at line pressure and temperature using an optical phase detector to distinguish between oil, gas, and water. It has a full operating range spanning from heavy oil to gas condensate.

When combined with the PhaseTester multiphase flowmeter, the PhaseSampler service is designed to improve multiphase flow rate measurements. In addition, the collection of phase representative samples allows a full recombination PVT study to be performed using the improved recombination ratio at line conditions.

A Russian operator used the service to conduct a comprehensive well testing campaign in a gas condensate field in Western Siberia. By using this service, the operator was able to accurately measure the reservoir fluid properties and rates to optimize production. It also enabled a better understanding of the transient nature of reservoir fluid composition during a multirate test and allocation of multiphase flow in commingled situations.

The service offers strong advantages over conventional sampling, the company said. It has a smaller footprint at the well site and captures individual phases of oil, gas, and water at live conditions in a multiphase flow. www.slb.com

Unit monitors harsh environments

Sensornet has launched its Oryx distributed temperature sensing (DTS) unit, designed for monitoring applications from desert to sub-zero conditions. Combined with satellite, radio link, or fiber communications, the Oryx becomes a powerful remote logging DTS unit.

The system, which can operate on solar or wind power, has a continuous monitoring range of up to 16,400 ft (5,000 m) and a sampling resolution of 3 ft (1 m). It can operate in environmental temperatures from 104ºF to 149ºF (-40ºC to 65ºC). The housing enclosure is rated IP66 or above to ensure weather- and dust-proof deployment.

The Oryx includes flexible communications options and a direct link to PCs or laptops. Set-up, channel configuration, and measurement can be performed remotely, eliminating proximity to the DTS unit at the wellsite location. Additional onboard memory ensures a high quantity of measurements can be taken, ideal for “drive-by” collection of data where a communications system would be cost-prohibitive. www.sensornet.co.uk

Targeting shale fracturing applications

Schlumberger has released its StimMORE fluid diversion service for diverting fracture treatments along a well bore in cemented or openhole completions. Used in combination with the StimMAP LIVE hydraulic fracture stimulation diagnostics service, which delivers microseismic data while the fracture treatment is pumped, the StimMORE service allows real-time optimization of fracture treatments.

The StimMORE service can be used in most well geometries and is ideally suited to horizontal well bores, both cased hole and openhole, up to a maximum temperature of 250ºF (121ºC). This service is especially well suited for use in shale formations.

The diversion slurries can be pumped on the fly as part of the main treating fluid, diverting the fracture as needed based on the real-time integration of microseismic data. The slurries are based on standard fracturing fluids and proppants, with the addition of a proprietary mix of materials that enable fracture diversion.

"The StimMORE service is part of the Contact portfolio of staged fracturing and completion services. These technologies allow us to create complex drainage patterns within the reservoir that enable access to reserves that may have otherwise been left in place," said Don Conkle, stimulation vice president, Well Services, Schlumberger.
The StimMORE re-fracturing treatment was recently applied to a major operator’s horizontal well in the Barnett Shale. Initial gas production of 2,200 Mcf/d had declined to less than 500 Mcf/d over a four-year period. The StimMORE service, coupled with the StimMAP LIVE real-time fracture monitoring service, enabled efficient and cost-effective coverage of previously unstimulated well sections, resulting in a net increase in estimated ultimate recovery of 0.7 Bcf. The StimMORE service can be used in fracture diversion despite complex completion scenarios. www.slb.com/reservoircontact

New software for predicting pore pressure

GeoMechanics International Inc. (GMI) has released GMI•PressCheck, a software package for predicting pore pressure and fracture gradient. The product includes tools for rapid import, manipulation, and combination of wireline logging data. GMI•PressCheck allows the user to easily smooth and filter logs as well as perform numerous calculations based on the logs. Tools for determination of overburden and compaction trends are flexible and easy to use. The software includes advanced features such as centroid and buoyancy analysis.

GMI•PressCheck is part of GMI’s suite of software packages for building geomechanical models and for predicting wellbore stability. Pore pressure and fracture gradient information are easily exported to GMI•WellCheck for wellbore stability analysis. www.geomi.com