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Baker Hughes Inaugurates New Center for Technology Innovation
Baker Hughes has inaugurated Phase I
of its new Center for Technology Innovation (CTI) in
northwest Houston.
“The CTI is a world class research and engineering center.
This $42 million investment demonstrates our company’s
commitment to developing new completion and production
technologies,” said Chad Deaton, Baker Hughes Chairman,
President and CEO.
“The CTI is capable of testing full-size prototypes of the
next generation of downhole completion tools in a test
environment with pressures up to 40,000 psi and temperatures
up to 700° F,” said Bennett Richard, Director of Product
Engineering.
The CTI is designed to enable Baker Hughes research and
engineering teams to achieve breakthroughs in technologies
focused on four important application areas: 1) Deepwater
wells 2) Extreme high-pressure, high-temperature (HPHT)
applications 3) Production optimization, and 4)
Large-diameter “big bore” completions.
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Baker Hughes at Technical Conferences
OTC Offshore Technology Conference
May 5 - 8
Houston, TX, USA
CSPG Canadian Society of Petroleum Geophysics
May 12 - 16
Calgary, Alberta, Canada
OGU 2008 12th Uzbekistan International Oil &
Gas Exhibition & Conference
May 13 - 15
Tachkkent, Uzbekistan
IADC Drilling Onshore America Conference & Exhibition
May 15
Houston, TX, USA
MOC 2008 Mediterranean Offshore Conference & Exhibition
May 20 - 22
Alexandra, Egypt
SPWLA 49th Annual Logging Symposium
May 25 - 28
Edinburgh, Scotland
View Tradeshow Calendar
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BakerHughesDirect is an e-business and knowledge management service, part of Baker Hughes’
overall Internet presence.
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Dear {FirstName} {LastName}: |
Volume 6, Number 4 |
Welcome to
Technology Update,
the Baker Hughes eNewsletter to inform you about our latest technologies for oil and gas drilling, formation evaluation,
completion and production. |
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Hughes Christensen Uses Innovative Technique to Create Additional Slot for an Offshore Congo Platform
Hughes Christensen helped a customer in the Congo accomplish a world-first by utilizing an innovative technique to create an additional slot on a platform in the Foukanda offshore field. The objective was to simultaneously drill and case off over 60 m (197 ft) of shallow formations using
Casing-while-Drilling (CwD) to enable the drilling of additional wells from the existing platform that had no further slot availability. A 30" diverter conductor pipe was positioned from the platform to the seabed. The pipe was manufactured with a pre-cut window and a 2° deflector inside that would allow drilling to be diverted from the existing eight directional wells, avoiding any collision. The recommended drilling assembly consisted of an
EZCase™ 24" bit and 20" casing rotated using a drive sub. The 66-m (217-ft) section was drilled successfully with returns to the sea. The EZCase bit and 20" casing were cemented in place, and the casing was connected to the surface wellhead as usual. ROP was controlled and averaged 7.5m/hr (24.6 ft/hr) on-bottom drilling, and the bit was drilled out in just over three hrs with a 16" GTX-CPT311 TCI bit. |
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INTEQ Uses EMTrak™ Telemetry System in Canada to Ensure Uninterrupted MWD Data Stream Under Lost Circulation Conditions
INTEQ has delivered critical Answers While Drilling services via its
EMTrak™ Electro-Magnetic telemetry system for a customer experiencing lost circulation and LCM problems on two rigs operating in Canada. Because the EMTrak system has no moving parts, it can handle more LCM products then mud-pulse telemetry tools—ensuring the operator a steady stream of downhole data in real-time. INTEQ drilled a total of 7900 m (25,918 ft) in 950+ hrs on three wells without incident or interruption to the MWD data stream. Based on the success of the wells, the service is being applied on more of the operator’s rigs, and will be included as part of a real-time pressure while drilling service. |
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Baker Hughes Drilling Fluids Uses BLACK MAGIC™ Spotting Fluid to Free $2 Million Drill String in South Texas
Baker Hughes Drilling Fluids recently experienced
another success with its
BLACK MAGIC™ spotting fluid for a South Texas customer. While drilling at 10,906 ft (3324 m), drill pipe became stuck after making a connection. The drilling mud weight of 12.3 lbs/gal was reduced to 11.5 lbs/gal to help the drill pipe become free while jarring. An 80 bbl BLACK MAGIC pill was built on location using mineral oil and weighted to 11.5 lbs/gal and spotted in the 14-3/4" hole. After running a free point indicator, it was determined that the drill pipe was stuck at 9876 ft (3010 m). A larger 230 bbl Black Magic pill was mixed at the Baker Hughes Drilling Fluids Hebbronville, Texas stock point. After backing the drill pipe off, the drilling jars were laid down and accelerator jars were picked up. After screwing back into the fish with the BLACK MAGIC pill in place for 36 hours, the drill pipe became free within 10 minutes after the jars hit six times. Because of its ability to free stuck pipe, BLACK MAGIC fluid was able to successfully recover the drill string containing $2 million of directional tools. |
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Baker Atlas Provides Segmented Bond Tool (SBT) Service with a Tractor in an 86° Deviated Well in Brazil
Baker Atlas Brazil recently used the
SBT service in conjunction with a tractor to complete three consecutive logging projects in Brazil. Specially designed rollers around the SBT instrument allowed the toolstring to reach an average inclination of 74°. Beyond that, the tractor was responsible for pulling the string to the maximum deviation of 86°. The effective use of force-modeling software and Deployment Risk Management methods made the SBT-logging operations a technical, operational and HS&E success. |
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Baker Oil Tools Provides Drilling and Completion Solution for Large-Bore Gas Producer in Malaysia with Total Loss Problems
Baker Oil Tools has delivered a solution for the drilling and completion of a large-bore gas producer in Malaysia with incurable total loss problems. The solution consists of a
ControlSET™ Uniflex Liner Hanger/Packer assembly coupled with a rock bit on a sacrificial motor, and a second assembly comprised of a
ZXP™ Tieback Packer with a Fluid Loss Control Valve. The Drill In Liner was run in hole after the customer set a balanced cement plug prior to penetrating the total losses zone. The 850 ft (259 m) of Drill In Liner washed and reamed 900 ft (274 m) of hardened cement patches before drilling out another 500 ft (152 m) of new hole in total losses condition. At the targeted TD, the Drill In Liner was successfully hung off, cemented and the packer set to test. This was followed by the installation of the Fluid Loss Control Valve tieback assembly, and the TCP perforation gun run with the HB-1 shifting tool. As expected, total losses resumed as soon as the guns were fired. By shifting the Fluid Loss Control Valve to close, the well was once again put back under control. |
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ProductionQuest Providing Monitoring Systems for Two Centrilift Seabed Production Boosting Systems in Deepwater Gulf of Mexico
ProductionQuest is providing
monitoring systems for two major deepwater seabed production boosting systems.
This is the first project using the Centrilift horizontal
electrical submersible pumping (ESP) system design for seabed
boosting in the Gulf of Mexico. The Cascade and Chinook development is located in the Walker Ridge area, 180 miles (300 km) south of the Louisiana coast. This project will use a floating production, storage and offloading (FPSO) facility and the customer plans to fast track both the FPSO and field development. The schedule calls for installation of the FPSO in early 2010 with first production in the first quarter of 2010. The FPSO will be located in approximately 8500 ft (2600 m) of water and will be the first in the U.S. Gulf of Mexico as well as the world's deepest FPSO to date. Cascade and Chinook will deploy Centrilift subsea electrical submersible pumping systems to boost production from the sea floor to the FPSO. Unlike conventional ESP installations, these seabed ESP systems will be installed in series in two subsea horizontal manifolds. New developments for this project include an ESP pod and vibration clamp rated to 16,000 psi working pressure. |
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Baker Petrolite F.O.A.M.™ Technology Achieves Dramatic Production Increases in High-Temperature Wells for North Sea Customer
A North Sea operator had a number of cycled high-temperature gas wells experiencing diminishing production rates. Baker Petrolite’s
F.O.A.M modeling software package helped to confirm liquid loading as the culprit. The Baker Petrolite team suggested a foamer treatment option that was best suited for the high-temperature conditions of the field. To minimize the risk of foam carry-over in the separator, the customer and Baker Petrolite team selected a suitable defoamer and applied it downstream of the wellhead. Well A showed an eight-fold increase in time online between shut-in periods. In addition, the required shut-in period was cut by half. Prior to foamer application, Well B could only support production flow for under a day. Following treatment this well was returned to continuous production without the need for any shut-in time. Before foamer treatment, Well C would not flow at all at standard conditions. This well returned to cycled production with a two-week online interval. Additional gas revenue generated by the chemical application to these three wells was valued at approximately $1.2M over a three-month period. |
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