MEA Winners
`
`93
`
`2003
`
`Engineering Innovation
`
`Judges choose top 14 industry projects
`H art’s E&P editors and staff proudly present the
`
`winners of the prestigious 2003 Special Meritorious
`Awards for Engineering Innovation.
`The pages that follow spotlight the 14 awards the judges
`picked as best of the 2003 crop of entries. The winners reached
`across a broad range of disciplines and addressed a number of
`problems that posed roadblocks to efficient operations. The
`resulting technologies opened new and better avenues to the
`complicated process of finding and producing hydrocarbons
`around the world.
`This year, some of the brightest minds in the industry from
`service and operating companies submitted a record number
`of entries representing better technology and new techniques
`for judges to consider.
`The award program honors engineering excellence and
`achievement in every segment of the petroleum industry. It
`recognizes new products and technologies that offer
`innovation in concept, design and application. Winning entries
`represent techniques and technologies that are most likely to
`solve costly problems and improve exploration, drilling and
`production efficiency and profitability.
`The people and companies that submitted the entries realize
`the oil- and gas-producing industry depends on new, better and
`constantly changing technological innovation to continue
`producing low-cost oil and gas from smaller and deeper
`
`reservoirs to feed an increasingly energy-hungry world.
`Contest judges chose the winners, but there were no losers
`in this contest. The products chosen represented the best of a
`long list of winners.
`The expert panel of judges included engineers and
`engineering managers from operating and consulting
`companies worldwide. They applied their expertise in areas in
`which they were familiar, and judges were excluded from
`categories in which they or their companies had a business
`interest.
`Hart’s E&P would like to thank these distinguished judges
`for their efforts in selecting the winners in this year’s
`competition.
`As in past years, Hart’s E&P will present the 2003 awards
`at the Offshore Technology Conference in Houston, Texas,
`May 5. The magazine would like to break this year’s record
`number of entries in next year’s contest. Individuals,
`companies and organizations are working around the clock
`on new technology that will improve the industry’s efficiency,
`and those efforts should get the public attention they
`deserve.
`An entry form for the 2004 Special Meritorious Awards for
`Engineering Innovation contest is available at the magazine
`Web site at www.eandpnet.com. The deadline for entries is
`Dec. 1, 2003.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`94 MEA Winners
`
`2003
`
`MEA Winners
`
`Si-Flex Accelerometer
`Input/Output
`
`Digital Hydraulics
`WellDynamics
`
`VectorSeis System Four VR
`Input/Output
`
`C-TECH “Precision Strength” Syntactic Foam
`Cuming Corp.
`
`GeoTap formation testing service
`Halliburton, Sperry-Sun
`
`Fiber Optic In-Well Seismic System
`Weatherford Completion Systems
`
`Score 100 Coring
`Corpro Systems Ltd.
`
`BJ Python Composite Bridge Plug
`BJ Services Co.
`
`Expandable Drill Bit - “XpandaBit”
`Weatherford International Inc.
`
`Accolade drilling fluid system
`Halliburton Energy Services Inc.
`
`GoFlo
`Subsea 7/Halliburton
`
`RamPump
`Weatherford Artificial Lift
`
`Trapped Pressure Compensator
`Nam/Halliburton
`
`Deepwater Sulfate Removal
`Marathon Oil Co.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`96 MEA Winners
`
`2003
`
`MEA Judges
`
`David Burnett
`Texas A&M University
`
`Peter Duncan
`Society of Exploration Geophysicists
`
`George King
`BP America
`
`Roger Knight
`McMoran
`
`Eve Sprunt
`ChevronTexaco
`
`Cheryl Stark
`BP America
`
`Donald Duttlinger
`Petroleum Technology Transfer Council
`
`Keith Millheim
`Anadarko Petroleum Corp.
`
`John Thorogood
`BP Amoco Exploration (Faroes)
`
`Bev Edwards
`Vanco Energy Co.
`
`Richard Ellis
`Mullen Energy Corp.
`
`David Murphy
`Shell Technology E&P
`
`Jerome Schubert
`Texas A&M University
`
`Tim Tipton
`Marathon Oil
`
`Svein Tollefsen
`Statoil ASA
`
`Dick Ghiselin
`Qittitut Consulting LLC
`
`Lanny Shoeling
`Shell Exploration & Production Co.
`
`John Toups
`Westport Technology Center International
`
`Bob A. Hardage
`Bureau of Economic Geology
`
`Yoram Shoham
`Shell International Exploration &
`Production Inc.
`
`Doug White
`ConocoPhillips
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`98 MEA Winners
`
`EXPLORATION, INDIVIDUAL EQUIPMENT: SI-FLEX ACCELEROMETER
`MEMS reduces seismic acquisition system size
`
`INPUT/OUTPUT
`
`Developed to detect and record seismic
`reflections, Input/Output’s Si-Flex
`accelerometer provides a low-noise, low-
`distortion sensor with exceptional
`bandwidth, dynamic range, stability and
`robustness.
`Ultimately, designers hoped to replace
`analog geophones with a technology for
`improved frequency response, performance
`and reliability along with reduced sensor
`size and weight. Along the way, they
`identified additional applications: vehicle
`control systems, platform leveling,
`earthquake protection systems, intrusion
`detection, equipment vibration control and
`protection, construction equipment and
`structure modal studies.
`This electrostatic force rebalanced
`microelectromechanical system (MEMS)
`accelerometer enables accurate seismic
`measurements over a wide dynamic range. It
`incorporates a bulk micromachined
`capacitive accelerometer die and a closed-
`loop, force-feedback application-specific
`integrated circuit to produce a digital output.
`Use of the Si-Flex accelerometer in land,
`
`in-well and ocean-bottom seismic
`imaging systems significantly
`reduces acquisition system and
`sensor size and weight. In ocean-
`bottom seismic acquisition systems,
`the accelerometer allows sensors to
`operate at any inclination angle and
`measure sensor deployment angles
`directly, eliminating the need for
`expensive gimbal receiver units that
`create data artifacts. High vector
`fidelity, along with improved
`linearity and bandwidth at all tilt
`angles, makes these sensors ideally
`suited for recording the full seismic
`vector wave field much better than
`with existing omnidirectional
`geophones.
`Operators have enjoyed improved
`and cost-effective imaging of direct
`hydrocarbon indicators, low-
`impedance reservoirs, complex thrust-
`faulted terrain and direct access to
`quantitative rock and fluid properties. When
`seismic data acquired with Input/Output’s
`VectorSeis ocean-bottom trials were
`
`The Si-Flex accelerometer enables significant reductions
`in acquisition system and sensor size and weight.
`
`compared to legacy datasets acquired with
`gimbaled sensors in the same area,
`VectorSeis data demonstrated measurable
`and significant improvements in vector
`fidelity.
`
`EXPLORATION, SYSTEMS: VECTORSEIS SYSTEM FOUR VR
`INPUT/OUTPUT
`Multicomponent seismic recording improves imaging
`
`Designed for multicomponent (full-vector)
`seismic recording in land and transition
`zone environments, the VectorSeis System
`Four VR is the first commercial seismic
`system to use microelectromechanical
`system (MEMS) accelerometers.
`Full-vector seismic recording enables
`improved P-wave imaging, converted wave
`imaging and full, nine-component imaging.
`Seismic surveys then can image
`stratigraphic and structural detail and
`provide improved visibility in such difficult
`areas as gas clouds and gas chimneys.
`The accelerometer operates in the full
`range of gravity, from right side up to
`horizontal to upside down, with 40-nano-G
`sensitivity and 100 dB of dynamic range.
`This reduces time spent manually orienting
`transducers.
`The multicomponent VectorSeis sensor
`module is autonomous and intelligent,
`interfaced via a cable with a digital
`telemetry and power delivery system.
`Simpler logistics and improved operational
`efficiency result from a single sensor
`
`module instead of a multielement
`string of geophones.
`The system reduces equipment
`weight 35% over conventional
`systems and 60% over conventional
`multicomponent operations.
`Manpower requirements and
`health, safety and environment
`exposure also are reduced.
`Conventional acquisition and
`processing cycle time is cut by up to
`10%, and multicomponent recording
`by up to 25%.
`In northern Alberta the
`VectorSeis System Four VR has
`improved structural and
`stratigraphic imaging in heavy oil
`sands. Special techniques
`dependent on accurate horizontal
`drilling enable exploitation of these
`enormous reserves, but poor structural
`imaging with conventional seismic
`surveying techniques has hampered
`economic success. VectorSeis
`multicomponent technology provides
`
`The VectorSeis System Four VR incorporates TrueDigital
`microelectromechanical systems accelerometers to
`image structural and stratigraphic detail in land and
`transition zone environments.
`
`superior structural imaging in such areas.
`Shear data are being studied as an indicator
`of lithology, redirecting client resources
`from high-density exploratory drilling to
`production.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`100 MEA Winners
`
`SUBSURFACE ANALYSIS, INDIVIDUAL EQUIPMENT: GEOTAP FORMATION TESTER HALLIBURTON, SPERRY-SUN
`While-drilling service estimates pressure near the bit
`
`Unlike conventional designs that use
`hydraulic or inflated packers and cannot
`take measurements with pumps on,
`Halliburton Sperry-Sun’s GeoTap
`formation tester provides subsurface
`pressure measurements using downhole
`hydraulics and a single pad/probe design.
`With this service, estimates of
`formation pressure can be made near the
`bit, which provides critical information
`during the drilling process.
`Pressure tests, with pumps on or off,
`are achieved in 5 to 10 minutes,
`dependent on formation permeability.
`The tester replaces wireline or pipe-
`conveyed logging services, which are
`time-intensive and represent higher
`operational risk.
`Using a closed hydraulic system,
`battery power and quartz and strain
`gauges, the sensor extends a probe on
`command to establish a seal at the
`borehole wall. It then performs a
`drawdown and build-up sequence to
`define formation pressure. This
`information is stored to memory and sent
`
`to a surface data unit
`for analysis and use
`in real time.
`The tester has
`reached total well
`depth determining
`measurement before
`borehole
`degradation as well
`as hydrocarbon
`typing and fluid
`contact
`determination via
`pressure gradients.
`A North Sea
`operator used GeoTap
`to measure reservoir
`pressure while drilling
`from a semisubmersible rig. The
`reservoir fluids gradient obtained was
`identical to that obtained by a wireline-
`type formation tester run in an adjacent
`well at 0.28 psi/ft. GeoTap eliminated the
`risk and cost of pipe-conveyed wireline
`testing, saving the operator more than US
`$350,000.
`
`The GeoTap formation tester provides subsurface pressure measurements
`in real time using downhole hydraulics and a single pad/probe design.
`
`A Gulf of Mexico operator deployed
`GeoTap in deep water after
`unsuccessfully attempting to obtain
`reservoir pressures with a wireline-type
`formation tester. The service delivered
`the required data at a savings of more
`than $500,000 compared to drillpipe-
`conveyed logging.
`
`SUBSURFACE CHARACTERIZATION AND ANALYSIS, SYSTEMS: SCORE 100 CORING
`CORPRO SYSTEMS LTD.
`System restricts sampling to proven targets
`
`Seeking to reduce the “dead time” involved
`in drillstring tripping in and out of a wellbore
`to retrieve core samples, Corpro Systems
`Ltd. developed the Score 100 system.
`Lack of available data at the time of
`selecting the coring point can easily
`compromise coring operations, resulting in
`the missing of a target sample. Using electric
`logs to select specific zones of interest,
`Score 100 can cost-effectively restrict coring
`to proven targets. And using the exploration
`well for more complete formation
`evaluation data acquisition negates the need
`for an additional appraisal well – a direct
`savings for the operator and the
`environment.
`This wireline-operated coring system
`obtains representative fresh state formation
`samples from existing wellbores (open or
`cased) without length restriction. Modules
`enable configuration for various
`applications, such as coring to evaluate
`residual fluids distribution in mature field
`wells and identify reasons for production
`decline.
`Comprising a coring assembly and a
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`included retrieval of downhole samples at
`the Aberdeen Drilling School test rig site.
`Additional tools are being constructed for
`commercial use.
`
`SCORE 100
`SCORE 100
`
`WIRELINE
`UNIT
`MONITORING
`ON SURFACE
`
`SIDE EXIT MANDRELL
`
`Step 2
`Score lateral
`micro-well
`
`Step 3
`Adjust whipstock
`position and Score
`multi lateral micro-
`wells
`
`caterpillar tractor unit, the system uses a
`dormant whipstock integrated with a
`conventional drillstring to exit from
`the primary wellbore at an angle of 4
`degrees. A 11/2-in.
`diameter core is cut
`and retrieved in a 2.4-
`in. diameter hole
`using the lower coring
`assembly. The tractor
`unit applies weight on
`bit or pulling power of
`up to 6,000 lb. A series
`of pressure
`transducers and a
`hydraulic system
`controlled from the
`surface through the
`wireline interface
`enable system
`monitoring.
`The tool can with-
`stand temperatures to
`247˚F (120˚C) and
`pressures to 10,000
`psi. Prototype testing
`
`DRILL PIPE SET
`LOOSELY IN SLIPS
`
`CONTROL UNIT
`
`CATERPILLAR
`TRACTOR
`
`PDM
`
`CORING
`ASSEMBLY
`
`Step 1
`Run drill string in
`hole and position
`whipstock
`RIH with Score 100
`Assy on wireline
`
`The Score 100 system enables low-invasion coring of multiple
`objectives from existing open or cased holes.
`
`MEGCO Ex. 1024
`
`

`

`102 MEA Winners
`
`WELLBORE CONSTRUCTION, INDIVIDUAL EQUIPMENT: EXPANDABIT
`WEATHERFORD INTERNATIONAL INC.
`Expandable drill bit hydraulics ease casing drilling
`
`Restricted clearance casing programs
`call for a hole larger than the internal
`diameter of the previous casing string.
`Underreamers and bicenter bits have
`limitations on their ability to reliably
`expand the hole, and bicenter bits often
`provide nonuniform directional
`response.
`One method of casing drilling requires
`a bit that can be retrieved through the
`casing string. This requires a device with
`a formation cutting structure
`indistinguishable from a standard PDC
`bit but capable of being withdrawn
`through a restriction significantly
`smaller than the borehole size just
`drilled.
`Weatherford’s XpandaBit can enlarge
`the borehole below a restriction in either
`the casing string or wellhead; it can drill
`a hole diameter up to 45% larger than the
`pass-through diameter.
`The drill bit’s body has four or more
`arms. Displacement of the outer cylinder
`causes the arms to move between a first
`(closed) and second (open) position. A
`
`pressure drop created by flowing drilling
`fluid at the head of the bit hydraulically
`actuates the tool.
`Internal hydraulic pressure moves the
`outer cylinder axially upward,
`compressing the string and drawing the
`blades upward, over the profile of the
`head, into the expanded position. The
`blades are constrained within slots in the
`head for greater rigidity and as a means
`of transmitting torque. Guide pins act on
`the slots to ensure that the blades return
`to the closed position on removal of the
`pressure differential.
`Drilling with casing has proven to be a
`safe, efficient method of wellbore
`construction. The XpandaBit tool can
`drill ahead of the casing string and then
`be collapsed and retrieved through the
`casing string. This ensures a consistent
`gauge hole and eliminates the
`inefficiencies of underreaming.
`
`Weatherford’s XpandaBit can enlarge the
`borehole below a restriction in either the casing
`string or wellhead.
`
`WELLBORE CONSTRUCTION, SYSTEMS: ACCOLADE DRILLING FLUID
`HALLIBURTON ENERGY SERVICES INC.
`Synthetic-base fluid reduces downhole losses
`
`Standard additives like lignite and
`organophilic clays contribute to high
`coldwater viscosities in deepwater
`drilling. To combat this, Halliburton
`formulated the Accolade system, an
`emulsion-based synthetic-base drilling
`fluid system (SBF) that contains no
`commercial clay or lignite additives.
`The fluid’s emulsion characteristics
`control rheological and fluid loss
`properties. The base oil is an ester-
`internal olefin (IO) blend, and due to its
`vegetable ester component, it is more
`biodegradable than conventional SBFs.
`The Accolade system’s low- and high-
`temperature – 40˚F to 350˚F (4˚C to
`176˚C) – rheological properties allow
`unprecedented control over viscosity
`and equivalent circulating density. The
`fluid’s gel strengths develop quickly but
`are fragile. The mud losses normally
`associated with tripping, running casing,
`cementing and breaking circulation are
`minimal when compared to wells using
`traditional SBFs. The high gel yet fragile
`
`gel strengths also
`prevent barite
`settling and barite
`sag, two
`significant issues
`in Gulf of Mexico
`drilling operations.
`Product
`requirements are
`minimized,
`resulting in close
`to 40% less
`material needed at
`the rig for fluid
`maintenance. This
`translates into
`fewer crane lifts
`and reduced
`transportation expense.
`Operators have used the Accolade
`system in more than 50 Gulf of Mexico
`wells. Throughout 2002, one major
`independent operator saved an average
`of US $500,000 per well on an 11-well
`program. Effective hole cleaning and
`
`A major operator’s comparison between conventional synthetic-base
`fluid and Accolade whole mud losses on Gulf of Mexico offset wells
`shows significant reduction when the Accolade system is used.
`
`deepwater performance while cementing
`(with full returns) saved $2.5 million in
`rig time. And a record-setting Gulf of
`Mexico deepwater operation recorded
`80% less SBF lost overall while drilling,
`tripping, running casing and cementing,
`resulting in a savings of $1.3 million.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`104 MEA Winners
`
`COMPLETIONS, INDIVIDUAL EQUIPMENT: TRAPPED PRESSURE COMPENSATOR
`NAM/HALLIBURTON
`Tubing string tool tackles trapped annular fluids
`
`Trapped annular fluid pressures
`traditionally have required either
`expensive, high-grade casing or heavier
`casing with reduced internal diameter. With
`the Trapped Pressure Compensator,
`however, packers can be set in optimal
`positions, and larger, less expensive casing
`and tubulars can be used to significantly
`increase production rates.
`By ensuring that trapped annular
`pressures never reach critical limits,
`rupture and collapse of tubulars and
`lightweight production casing is avoided.
`This prevents exposure of unprotected
`formations behind the casing to completion
`fluids and exposure of the surface casing to
`dangerous pressures. Operators enjoy
`higher production efficiency as well as
`enhanced safety.
`Designed as a transparent member of the
`tubing string, the Trapped Pressure
`Compensator is a sealed, nitrogen-filled
`chamber installed in the tubing string and
`inserted inside the casing of a well to
`prevent pressure created by trapped
`annular completion fluid from rupturing or
`
`collapsing the casing.
`At the 30-year-old Eemskanaal-2 well in
`Groningen field, Holland, Shell Oil Co.
`subsidiary Nederlandse Aardolie
`Naatchappij BV (NAM)/Halliburton
`replaced the completion equipment by
`stabbing a tailpipe assembly onto a 75/8-in.
`liner top at 3,773-ft (1,151-m) depths and
`then setting a packer above in 10 3/4-in.
`casing. This created a 328-ft (100-m)
`trapped column of annular fluid where
`lightweight casing preexisted in the well.
`Once the trapped pressure problem
`was solved, Nam was able to run the
`world’s first commercial application of
`13% chromium expandable tubulars and
`proprietary expandable gas-tight
`connections in the preexisting liner below
`the column of trapped annular pressure.
`The 6,095-ft (1,859-m) section of 6-in.
`corrosion-resistant alloy cased-hole liner
`system also set a world record as the
`longest solid tubular expansion in a
`single run.
`When in place, the liner was expanded
`inside 75/8-in. casing, creating a 60% larger
`
`The Trapped Pressure Compensator installed in a
`Solid Expandable Tubular liner completion
`maintains a desired annular pressure.
`
`production conduit compared to the 51/2-in.
`tubing it replaced. Production from the well
`increased 60%.
`
`COMPLETIONS, SYSTEMS: DIGITAL HYDRAULICS
`WELLDYNAMICS
`Hydraulic system controls multiple reservoir zones
`
`Designed to address the requirements of
`the lower end of the intelligent completion
`market with simple hydraulic on and off
`control of reservoir intervals, Digital
`Hydraulics is a closed-loop, hydraulic well
`control system that uses the presence or
`absence of pressure to communicate
`between a surface controller and
`downhole tools.
`Based on this concept, the Halliburton
`Energy Services and Shell Technology
`Ventures joint venture known as
`WellDynamics designed a SmartWell
`system that uses three 1/4-in. hydraulic
`control lines to independently manage
`up to six flow control devices; four lines
`can control 24 devices. Each tool can be
`hydraulically pressurized from the
`surface in either direction, open to
`closed or closed to open, requiring no
`downhole springs or gas charges.
`The system can deliver a force greater
`than 40,000 lb to crush scale buildup,
`sand, debris or other obstructions.
`Offshore Brunei, operators completed
`a workover of a “snake” well (maximum
`
`deviation of 5
`degrees) with five
`commingled
`production zones
`using Digital
`Hydraulics. The
`well holds the
`world record for the
`maximum number
`of zones controlled
`in real time from
`the surface.
`In Oman,
`operators used the
`system to complete
`a four-leg,
`horizontal
`multilateral
`producer with
`waterflood and
`an electric
`submersible pump
`(ESP). A special hydraulic wet
`disconnect allowed ESP removal while
`leaving the lower completion – including
`the flow control devices – in the well.
`
`The Digital Hydraulics system enables operators to control multiple
`reservoir zones.
`
`Real-time manipulation of all zones
`resulted in an oil production increase
`from 315 b/d to 1,510 b/d and a water cut
`improvement from 97% to 74%.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`106 MEA Winners
`
`PRODUCTION, INDIVIDUAL EQUIPMENT: C-TECH PRECISION STRENGTH SYNTACTIC FOAM
`Microspheres protect high-pressure wells
`
`CUMING CORP.
`
`To safeguard wells – and multibillion-dollar
`production programs – from casing
`collapse as a result of unanticipated
`pressures and temperatures, operators
`require reliable protection for hot,
`ultradeep well casings.
`Cuming Corp.’s C-Tech Precision
`Strength Syntactic Foam protects
`ultradeep wells from transient
`overpressures below the mudline that
`endanger well casings.
`The foam is a rigid, solid casing liner
`material that collapses under precisely
`defined conditions to protect high-
`temperature, high-pressure offshore oil
`and gas wells. Made of tiny, hollow glass
`microspheres in a high-temperature epoxy
`binder, the foam’s properties can be
`adjusted to suit a range of conditions
`inside a given well, or varied from one well
`to another.
`The material is cast directly onto the
`casing’s outer diameter by a patented
`process. Each grade of syntactic foam is
`engineered with a specific set of
`characteristics, tailored for the region in
`
`which the well operates.
`At startup, the materials
`remain intact. As pressure and
`temperature in the well rise
`during operations, the
`materials compress and
`relieve pressure in the
`confined space of the annulus.
`Finally, when conditions reach
`predetermined limits, the
`foam collapses, preventing
`excessive overpressure and
`protecting the steel casing.
`A passive system, C-Tech
`requires no controls or active
`intervention. It responds
`automatically to
`overpressures and
`temperature spikes.
`BP America has used the
`foam to protect wells in its
`Thunder Horse field, where
`water depths reach 6,000 ft
`(1,830 m) and flowing
`temperatures reach 270˚F
`(132˚C), since early 2002.
`
`C-Tech protects deepwater wells against overpressure.
`
`PRODUCTION, SYSTEMS: FIBER-OPTIC IN-WELL SEISMIC SYSTEM
`WEATHERFORD COMPLETION SYSTEMS
`Downhole sensing enables continuous data collection
`
`Permanent in-well seismic sensing allows
`for a range of applications, particularly in
`the production phase, by allowing time-
`lapse (4-D) imaging and continuous
`seismic monitoring. Not only can 4-D
`surface seismic data be calibrated to
`production data, but used independently,
`in-well seismic sensors are a cost-
`effective way to obtain information away
`from the wellbore on an ongoing basis.
`Weatherford’s In-Well Seismic System
`incorporates advanced, high-performance
`optical instrumentation and miniature
`optical accelerometers and hydrophones
`for comprehensive, four-component
`downhole sensing.
`Using Fiber Bragg Gratings, the system
`architecture allows in-well seismic sensor
`arrays to be deployed on a single cable
`without use of downhole electronics or
`optical couplers. Optical instrumentation
`at the surface allows interface to seismic
`recording systems and complex
`integrated surveys. It also permits
`independent, continuous seismic data
`
`collection for standalone
`reservoir monitoring.
`The system’s slim-profile,
`optomechanical seismic sensors
`can withstand the rigors of
`permanent downhole deployment
`on tubing or casing and fit within
`the tight spatial constraints of
`wellbores. These devices achieve
`high sensitivity, wide bandwidth
`and large dynamic range without
`the need for complex downhole
`signal conditioning, amplification
`and filtering typically found in
`electronic sensors.
`TotalFinaElf recently deployed
`the optical seismic system at the
`Izaute field in southwest France.
`The multistation optical seismic
`system was tubing-conveyed with
`the accelerometers optimally
`coupled to the casing. The operator used
`five multicomponent (3-C) seismic
`stations for a walkaway vertical seismic
`profile survey (VSP) and plans repeat VSP
`
`Weatherford designed its in-well optical seismic system to
`meet the challenging requirements of long-term,
`permanent, in-well seismic imaging and monitoring.
`
`surveys for time-lapse imaging. A sixth 3-
`C station, installed at the reservoir level,
`will enable continuous recording of
`microseismic events.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`108 MEA Winners
`
`REMEDIATION, INDIVIDUAL EQUIPMENT: PYTHON COMPOSITE BRIDGE PLUG
`Easy plug removal slashes mill out times
`
`BJ SERVICES CO.
`
`The BJ Python, comprised of high-technology composite material, is available in high-, medium- and
`low-temperature ratings.
`
`Engineered to meet the requirements
`of the most challenging, deep, high-
`temperature and high-pressure wells,
`the BJ Python Composite Bridge Plug
`can operate at temperatures beyond
`350˚F (176˚C) with pressure
`differentials in excess of 10,000 psi.
`A noncircular mandrel and tapered
`mating parts are used to rotationally
`lock all components, including the
`packing element. As a result the plug is
`easily removed after fracturing using
`conventional coiled tubing motors and
`junk mills. This intrinsic rotational lock
`results in reduced mill-out times on
`coiled tubing, predictability in the mill-
`out process and significant cost
`savings to operators.
`In August 2002, BJ Services set
`the first 31/ 2-in. BJ Python Plug for a
`South Texas operator in Starr County.
`The plug was set at an 11,626-ft
`(3,546-m) TVD and a static temperature
`of 293˚F (145˚C).
`The following September, BJ
`Services set the 31/ 2-in. plug for a South
`
`Texas operator in
`Duval County. The plug
`was set at a 15,640-ft
`(4,770-m) TVD and a
`static temperature of
`435˚F (223˚C). The
`differential pressure
`applied during the
`subsequent stimulation
`procedure was 4,483
`psi. The plug was
`milled out in 1 hour and
`55 minutes.
`
`350˚F
`
`10,000 psi
`
`31/2 in.
`
`BJ PYTHON COMPOSITE BRIDGE PLUG APPLICATIONS
`Temperature
`Pressure
`Casing OD
`Casing weight
`range
`9.2-10.2 lb/ft.
`12.7 lb/ft.
`9.5-15.1 lb/ft.
`20-23 lb/ft.
`23-26.8 lb/ft.
`9.2 lb/ft.
`9.5-15.1 lb/ft.
`14-20 lb/ft.
`14-20 lb/ft.
`
`275˚F
`
`200˚F
`
`6,000 psi
`
`5,000 psi
`
`41/2 in.
`
`51/2 in.
`31/2 in.
`41/2 in.
`51/2 in.
`51/2 in.
`
`REMEDIATION, SYSTEMS: GOFLO
`SUBSEA 7/HALLIBURTON
`Coiled tubing, chemicals clear pipeline debris
`
`A combination of well servicing
`technologies, chemical applications and
`subsea pipeline access capabilities, the
`GoFlow flowline intervention system
`tackles pipeline blockage.
`Driven to provide a solution to a range of
`pipeline blockages, designers came up with
`a system that improves pipeline inspection
`capabilities while enabling cost reduction
`on new field developments.
`A traction device powered by a
`hydraulically driven turbine is used to pull
`neutrally buoyant coiled tubing into
`pipelines. The remediation fluid passes
`through the coiled tubing conduit and
`tractor and exits through a hydraulic jetting
`assembly. The hydraulic jets’ mechanical
`action removes debris from the pipeline
`walls. The debris then is treated with
`preselected chemicals to ensure that it does
`not re-adhere to the pipe wall or other
`particles.
`The system is designed to enable a
`common application process in removal of
`paraffin wax, hydrates and scales. The
`system also can be used to remove sand,
`
`other well debris and
`failed mechanical
`components, such as
`stuck pigs.
`This intrusive
`remediation system
`enables operators to
`accept a higher risk of
`pipeline blockage and
`reduces the cost of
`initial field development
`by reducing the
`requirement for flow
`assurance solutions.
`Flowline intervention
`also is a quicker method
`of reinstating pipelines
`than replacement.
`Finally, it offers a less
`risky solution than
`conventional pigging.
`Future developments
`may include the
`adaptation of downhole
`video inspection technology for flow lines
`and the use of well logging tools to enable
`
`The GoFlow system removes paraffin wax, hydrates, scales, sand and
`well debris.
`
`high-resolution, real-time inspection of flow
`lines and pipelines.
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`MEGCO Ex. 1024
`
`

`

`110 MEA Winners
`
`FACILITIES, INDIVIDUAL EQUIPMENT: RAMPUMP
`WEATHERFORD ARTIFICIAL LIFT
`Multiphase pump boosts production in GOM
`
`The Weatherford RamPump multiphase
`booster lowers back pressure in flow
`lines from wells and production
`gathering systems.
`The pump handles a range of flows,
`from heavy oil to wet gas. The injectable
`seal allows the operator to maintain
`packing during operation without
`shutting down. In addition, this unit can
`simultaneously lower back pressure
`while using the pumped product to
`reinject.
`Designed to handle sandy flow
`streams, the RamPump is ideal for
`situations requiring wellhead pressure
`reduction, pipeline pressure boosting,
`wet gas compression, produced gas
`reinjection for gas lift, well stimulation
`and testing, and pressure maintenance
`for hydrate inhibition. Additional
`applications may include acid gas
`injection, water injection and disposal
`and liquid carbon dioxide injection. Gas
`reinjection for underbalanced drilling
`systems and high-pressure (5,000 psi)
`fluids injection also are possible.
`
`On a recent Gulf of
`Mexico installation,
`the RamPump’s 12-in.
`plungers with 60-in.
`stroke allowed a major
`independent oil and
`gas company to flow a
`well that otherwise
`would have been shut
`in due to high back
`pressure. Flowing
`tubing pressure was
`reduced from 600 psig
`to between 15 psig and
`250 psig while
`boosting the combined
`gas and liquids into a
`downstream separator
`at 1,000 psig.
`With the RamPump
`installed, the well was
`isolated from the high back pressure
`imposed by the HP separator, and the
`operator is seeing an estimated 150 b/d
`and 250 b/d of oil in incremental
`production.
`
`The hydraulically driven, positive displacement RamPump handles flows
`ranging from heavy oil to wet gas.
`
`Since its first installation in October
`1999, two additional installations have
`logged more than 24 months of
`continuous operation in the Gulf of
`Mexico.
`
`FACILITIES, SYSTEMS: DEEPWATER SULFATE REMOVAL
`MARATHON OIL CO.
`Desulfation improves flow assurance, cuts costs
`
`Sulfate scale and resultant loss of flow
`assurance occur when seawater is injected
`into offshore reservoirs containing barium,
`strontium and calcium. To eliminate the
`possibility of sulfate scale problems,
`Marathon Oil Co. developed a process that
`removes the sulfate ions from injected
`seawater using a membrane prior to
`injection.
`In deepwater field developments the use
`of subsea wells prohibits economical and
`practical use of inhibitors because
`specialized service vessels or service
`pipelines are required to perform the
`inhibitor treatments. Other impediments
`are commonly used shared flow lines from
`multiple subsea wellheads, multiple
`horizontal laterals and the lack of downhole
`zone isolation to control the placement and
`monitoring of inhibitor concentrations,
`necessary for determining the life of an
`effective squeeze treatment.
`Marathon developed the sulfate removal
`process in response to barite scaling
`problems on its Brae A platform in the
`
`w w w.EandPnet.com | Hart’s E&P | April 2003
`
`North Sea. The
`desulfation process
`involves use of a
`nanofiltration
`membrane that
`selectively rem