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Dr. Mark Zobak
Teaches Special Classes on Oilfield Geomechanics in Rio de Janeiro and Kuala Lumpur
Professor Mark Zoback taught a special two-day class
in March on Oilfield Geomechanics in Rio de Janeiro for an audience of 52
customers, most of them from Petrobras. The class leveraged the Baker Hughes’ acquisition of Geomechanics International (GMI)
in 2008. Another class also took place in Kuala Lumpur
during March. More than 42 customers attended, mostly from Petronas. Dr. Zoback
of Stanford University was one of the founders of GMI. He is an advisor to Baker
Hughes and a world-renowned expert in oilfield geomechanics. He was recently
selected by the American Geophysical Union to receive the AGU medal, reserved
for the most outstanding contributors in the field. He is also the author of the
book Reservoir Geomechanics.
Please visit the Baker Hughes exhibit at any of the
upcoming conferences to find out how our
latest products and services can advance your reservoir performance.
SPE Production and Operations Symposium
Oklahoma City, OK
April 4 - 8
Hart’s Developing Unconventional Gas (DUG)
Ft. Worth, TX
April 6 - 8
SPE Digital Energy Conference
Houston, TX
April 7 - 8
SPE International Symposium on Oilfield Chemistry
The Woodlands, TX
April 20 - 22
Williston Basin Petroleum Conference
Regina, Canada
April 26 - 28
SPE – ESP Workshop
The Woodlands, TX
April 29 - May 1
If you think your friends and colleagues might benefit from this
information, please send this newsletter to them,
subscription is free.
View past issues of the Baker Hughes Technology
Update e-Newsletter.
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Welcome to
Technology Update,
the Baker Hughes e-newsletter to inform you about our latest technologies for oil and gas drilling, formation evaluation,
completion and production.
Drilling & Evaluation
Europe
 Reservoir Navigation Services Ensure Precise Wellpath for Multilaterals in a North Sea Field
Reservoir Navigation Services (RNS) continue to deliver impressive results for a North Sea offshore field. Recently for the Grane
field, Baker Hughes provided an INTEQ AutoTrak™ integrated drilling and evaluation system, providing valuable RNS answers on two multilateral 8½” sections. RNS were delivered via 24/7
BEACON™
Remote Operations support from Stavanger.
Baker Hughes drilled the wells flawlessly in a single-bit run totaling 4,305 m (14,124 ft) and carefully navigated the reservoir section to penetrate approximately 3,005 m (9,859 ft) of pay. After drilling the first 1,300 m (4,265 ft) reservoir leg, an open-hole sidetrack was performed, and
Baker Hughes drilled the second leg from 2,175 to 5,180 m (7,136 to 16,995 ft). On both runs, the RNS ensured the wellpath remained ~8-9 m above the oil-water contact. In addition, the team proactively maneuvered the wellpath to avoid drilling into the troublesome Lista shales, which can result in hole problems. As a result, only 4.5 m (14.8 ft) of shale were penetrated on this leg – delivering close to 100% Net:Gross. The DeepTrak™ LWD response tracked the shale at a distance and the offset to the oil-water contact while the AziTrak™ service’s superior distance-to-bed calculations ensured that the customer had the right answers while drilling.
Middle East
 Baker Hughes Conducts the First-ever 100-Level 3D and Walkaway VSPs in Oman
Baker Hughes has successfully completed a seismic
project in Oman, deploying a 100-level seismic tool array – the first of its kind in the world. The
Baker Atlas Borehole Streamer Seismic Digital Array System
was deployed to record two walkaway lines, which were each 5-mile (8-km) long. The Borehole Streamer system
enables Baker Hughes to provide large 3DVSP and walkaway VSP for customers with minimal rig time. Over 64,000 source receiver pairs for the walkaway VSP survey were recorded, with a total operating time of 65 hours.
The skilled crews also acquired three stations of zero-offset VSP and recorded almost 800 channels of data.
Europe
 OMNIFLOW Drill-in Fluid Eases Drilling and
MICRO-WASH Fluid Significantly Increases Production from a North Sea Multilateral Well
The Baker Hughes Drilling Fluids
OMNIFLOW DIF
drill-in fluid was used to drill two opposing legs on a multilateral
well on the RITA project in the UK North Sea. The completion was
complicated, and used a total of 5,000 ft (1,524m) of sand screen in the horizontal sections. The well was planned to be suspended for several months so a
MICRO-WASH suspension fluid was left in the open hole in both legs. The Baker Hughes team designed the
MICRO-WASH fluid to eliminate the need for a high-density solids-laden completion fluid, and also to remove the filter cake from the wellbore and
minimize the risk of formation damage. The first leg was drilled in September, but due to operational problems the well was not brought on line until February. The predicted production from both legs was estimated to be a maximum of 50,000 mscfd. When the well was brought on, the first leg alone flowed at 60,000 mscfd and the second leg increased the production to 80,000 mscfd, which is the maximum
flow the production facilities can handle, which was way beyond the operator’s expectations.
Africa
 Quantec™ PDC Bit Saves $250,000 with a First-Ever Single Run in Algeria
Quantec technology has set a record One Fast Run™ in the Tiguentourine field in Algeria. Historically, the section, comprising hard abrasive sandstone, has been drilled using several
Hughes Christensen Impreg and TCI roller cone bits. After a first successful trial run drilling with a
8½" Quantec bit through the Cambro-Ordovician reservoir, the
Baker Hughes team modified the existing design to further optimize the PDC bit for this specific application. In the second run, the bit achieved a shoe-to-shoe run to TD with an outstanding ROP of 4.1 m/hr. This run doubled the fastest ROP of a competitor’s Impreg bit. Offset data indicates that no well was ever drilled from shoe-to-shoe until now. With this excellent performance, the
Quantec bit saved over $250,000 compared with the offset wells.
COMPLETION & PRODUCTION
Asia Pacific
 Baker Hughes and Operator Teamwork Yields Flawless Completion and Production Operations for Gian Cepu Field in Indonesia
Facing a short deadline for first oil expectations, Baker Hughes
worked with the operator to manufacture and deliver all specialized and corrosion-resistant equipment to the wellsite
in Indonesia. The Baker Hughes team flawlessly
installed the Baker Oil Tools nickel alloy cased hole completions
and then planned the perforating jobs with the proprietary Deployment Risk Management process and risk reduction technologies, which enable maximum gun-length deployment per run, therefore, minimizing the required rig time. The first two wells have been perforated successfully by using the
Baker Atlas
Predator XP™
PERFFORM
low-debris charge technology. As a result of many months of early consultation, the operator insisted on Baker
Hughes as the provider of on-site testing and Baker Petrolite specialty chemical treatments. The key challenges were near complete chemical removal of H2S from the crude oil, while simultaneously reducing the pour point of the crude to allow handling at ambient temperature. The targets
for both of these applications were surpassed through the use of
Baker Petrolite
SULFIX™ H2S Scavenger and a Paraffin Inhibitor, providing undetectable H2S levels and a pour point of 18°C for the produced crude. The scope of work is to complete six wells drilled to date on the giant onshore Cepu block, located between Central and East Java provinces, with total oil reserves estimate of 350 million barrels.
U.S. Land
 Baker Hughes Installs 20 REPacker Systems for Perforating/Frac Job in a Bakken Shale Well in North Dakota
Baker Hughes successfully installed 20 Baker Oil
Tools REPacker™ open-hole packer systems in one application in the Bakken
formation, Williston, North Dakota. This is the highest number of REPackers ever installed in one well worldwide. The 20 REPackers were run for a dual application of a 10-stage Frac-Point™ job on bottom and a nine-stage composite plug and perforating/frac job on top. The assembly was run in conjunction with a casing hanger packer with HR profile. TD on the well was 20,100 ft (6,126 m) and the horizontal section was 9,007 ft (2,745 m) long, the packers were installed successfully with minimal problems getting them to bottom with proper hole preparation using the reamer assembly.
Latin America
 XP ESP Systems with High-Horsepower Vanguard Technology to be Installed in Offshore Brazil’s Peregrino Field
Baker Hughes will install 30 Centrilift
Electrical Submersible Pumping (ESP) Systems in the Peregrino Field, offshore Brazil. The four-year, renewable contract is for the provision and servicing of downhole ESP systems for the field in 400 ft of water in the Campos Basin. The Peregrino project requires harsh environment XP systems, including the XP motor with Vanguard technology. The Centrilift solution was focused on system reliability, which will
reduce operational cost by minimizing interventions.
Europe
PETROSWEET™ Scavenger Reduces Mercaptan Odor from a Condensate Collection Tank in Italy
A customer in southern Italy wanted to reduce mercaptan odors emanating from
its condensate collection tank. On the basis of cost–performance and ease of implementation, the Baker
Hughes team selected the Baker Petrolite PETROSWEET™ Mercaptan Scavenger as the preferred means to reduce odors from the tank. The targeted key performance indicator (KPI) for this application was a reduction of mercaptan levels in the condensate by 50%-75%. After the treatment was initiated and optimized, an average of 18 ppm mercaptan was realized, which constitutes a 68% reduction in total mercaptan, reducing the odor around the collection tank. As a result, the PETROSWEET™ MS07767 Mercaptan Scavenger program remains the operator’s solution choice for cost–effective mercaptan scavenging in this field.
U.S. Gulf Coast
 SENTRYNET™ Alarm Saves Gulf of Mexico Operator $70,000 in Lost Production and Additional System Re-Start Expenses
A
SENTRYNET Remote Tank Level Inventory system, installed at an offshore platform in the Gulf of Mexico, recently prevented a facility shut-in and saved the operator $70,000 in lost production and prevented a system upset and re-start expenses. The system alerted the Baker Hughes manager via email that a
"low usage" condition occurred on the demulsifier injection system over night at this facility. After confirming the condition with
the monitoring staff, the Baker Hughes account manager called the offshore operator, who immediately confirmed that the chemical pump had failed. The failure was corrected, demulsifier injection restored, and production continued without incident. This entire monitoring and alert process occurred independently of the operator's own local automation package. The
Baker Hughes tank level monitoring system utilizes the SENTRYNET radio and satellite system linked to the Completion & Production
BEACON™ Center at the Baker Hughes Center for Technology Innovation (CTI) in Houston.
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