19.0 concept - low cost rotary steerable systems
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8/10/2019 19.0 Concept - Low Cost Rotary Steerable Systems
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SLIPGRIP –THE LOW COST ROTARY STEERABLE TOOL
“ Pr ov id i ng r ot ar y st eer ab le f unct iona l i t y
at st eer able mot or pr ices”
Background
Market & Applications
Technology
Commercialisation
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Mental Models• Rotary steerable tool means
– Complexity
– High capital cost
– High day rate
– Specialist operators
– Not suitable for low cost applications
• Not necessarily so ….
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Market needs• Improved drilling performance
• ROP improvements• Extension to operating envelopes
• Lateral extension
• Cost similar to steerable motors• Low cost of ownership
• Reduced specialist crew numbers
• Minimum MWD• GR only
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RST Characterisation
Maintenance and
Service costs
Specialist operators
$$$$$$$$$LIH cost
$$$$$$$$$Capital cost
3-D profile
Geosteering
FEMWD
Closed loop control
SlipGripIntermediatePremium
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SlipGrip
Competitor Positioning
Price
Perceived Value
Steerable motors
Premium RST
Intermediate RST
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Applications
TTRD3 3/8” prototype
R1 BHADisposable BHA for
mature fields and infill
drilling
DDWCDisposable BHA
Directional control
TBLThrough Bit Logging
SHDe.g. US coal bed
methane
Motor ReplacementRST functionality at
motor prices
SpecialistApplications
Low Cost RST
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Technical Description –
Dual operating mode
Lockingpiston
Outer sleeve
Inner sleeve
Torquetransmission
Drill stringconnection
Locking pistonreturn spring
The tool is cycled between directional drilling and performance
drilling mode by a combination of reciprocation and pressure
drop. The locking piston acts to couple the inner and outer sleeve
for performance drilling and decouple the two sleeves for
directional drilling.
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As the tool cycles from performance drilling to directional drilling
mode the three concentric stabiliser blades are forced out to
engage with the borehole wall. These blades act to prevent the
outer sleeve from rotating during directional drilling operations.
At the same time as the stabiliser blades are being manipulated
the rotation of the inner sleeve creates a bit offset in a point thebit fashion.
Technical Description –
Directional drilling operations
-
Inner sleeve
Concentric stabiliser Outer sleevePre-load springs
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Technical Risks• The product benefits from simplicity
• Principle technical risk
– Slippage during directional drilling– Washouts, collapse
• Mitigation
– Pad design and length,– Anti rotation device
– Weighted bias
– Operations procedures
• Possible limitation due to geology but needs to betested.
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Path to Market• Phase 1 Complete
– Proof of concept complete through SMART award
• Phase 2– Investment in commercial prototype and fieldtrial
• Phase 3
– Commercialisation– Sales to third parties
– Revenue from initial sale, annual royalty and
service agreements– Target markets
• USA
• North Sea
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Phase 2 Field Trial Project Plan
• Tool design
– 3 3/8”, 4 ¾” or 6 ½” field trial prototypes
• Bench test
• Secure field trial participation
• Manufacturing
• Field test
• Contingency & retest
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DEA Proposal Summary
• Development of a field ready 3 1/8” rotary steerable tool forTTRD applications
• Reservoir access using high build up rate RST
– High BUR 350/100ft
– Simple mechanical operation by pipe reciprocation
– Low capital cost
Proposer (s)
Duration Total cost Funding sought
15 months £540 k £190 k