Testing Next Generation LDAQ Technologies Protocols And First … · 2019. 1. 19. · METEC Goals 3...
Transcript of Testing Next Generation LDAQ Technologies Protocols And First … · 2019. 1. 19. · METEC Goals 3...
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Testing Next Generation LDAQ Technologies Protocols And First Results
Daniel Zimmerle
Methane Emissions Technology Evaluation Center
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METECH4
2
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METEC Goals
3
• Independent testing and validation at a neutral venue to
demonstrate technology and system performance
• Two official rounds of testing (R1 and R2)
• Opportunities for ad hoc testing
Goal #1: Gauge technical performance
Goal #2: Engage stakeholder community
• Facilitate more effective hand-off and post-MONITOR field testing by developers and operators
• Representative test site to engage stakeholders
• Engage operators in design & construction of test site
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CSU’s Background in Methane Measurement
4
ProductionMidstream Gathering
& Processing
M M
M
ConsumersDistribution or Major
Customers
Transmission System
Storage
Exploration&
Production
Gathering&
Processing
Transmission&
StorageDistribution
(B) Storage operated by distribution companies
EDF G&P Study2013-15
(Marchese et al.)
EDF T&S Study2012-15
(Zimmerle et al.)
Top-down / Bottom UpFayetteville Study Study (2014-16)
DOE Funded / Colorado School of Mines Prime(CSU: Zimmerle, et al.)
Gathering Compressor Emission Factors
2016-18(Zimmerle et al.)
Papers: CSU & Partners
1. Subramanian, R. et al. Methane Emissions from Natural Gas Compressor
Stations in the Transmission and Storage Sector: Measurements and Comparisons
with the EPA Greenhouse Gas Reporting Program Protocol. Environ. Sci.
Technol. 49, 3252–3261 (2015).
2. Zimmerle, D. J. et al. Methane Emissions from the Natural Gas Transmission
and Storage System in the United States. Environ. Sci. Technol. 49, 9374–9383
(2015).
3. Mitchell, A. L. et al. Measurements of Methane Emissions from Natural Gas
Gathering Facilities and Processing Plants: Measurement Results. Environ. Sci.
Technol. 49, 3219–3227 (2015).
4. Marchese, A. J. et al. Methane Emissions from United States Natural Gas
Gathering and Processing. Environ. Sci. Technol. 49, 10718–10727 (2015).
5. Bell, C. et al. Reconciliation of methane emission estimates from multiple
measurement techniques at natural gas production pads. Elem Sci Anth (2017).
6. Vaughn, T. L. et al. Comparing facility-level methane emission rate estimates
at natural gas gathering and boosting stations. Elem Sci Anth 5, (2017).
7. Zimmerle, D. J. et al. Gathering pipeline methane emissions in Fayetteville
shale pipelines and scoping guidelines for future pipeline measurement
campaigns. Elem Sci Anth 5, (2017).
8. Schwietzke, S. et al. Improved Mechanistic Understanding of Natural Gas
Methane Emissions from Spatially Resolved Aircraft Measurements. Environ.
Sci. Technol. (2017). doi:10.1021/acs.est.7b01810
9. Roscioli, J. R. et al. Measurements of methane emissions from natural gas
gathering facilities and processing plants: measurement methods. Atmos Meas
Tech 8, 2017–2035 (2015).
10. Robertson, A. M. et al. Variation in Methane Emission Rates from Well Pads
in Four Oil and Gas Basins with Contrasting Production Volumes and
Compositions. Environ. Sci. Technol. (2017). doi:10.1021/acs.est.7b00571
11. Yacovitch, T. I. et al. Natural gas facility methane emissions: measurements
by tracer flux ratio in two US natural gas producing basins. Elem Sci Anth 5,
(2017).
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Pad 5
5
45m x 60m well padDry setup
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Context
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Outlining a Potential Path To Equivalence
1. Establish a quantitative efficacy baseline for currently approved methods
2. Develop a technology-independent method to quantify equivalent emissions control and reduction
3. Develop a test & acceptance protocol for technology/method combinations.
4. Stakeholder preparation for the regulatory and policy adoption cycle
Poss
ible
to
wo
rk in
par
alle
l on
m
ult
iple
ste
ps
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Outlining a Potential Path To Equivalence
1. Establish a quantitative efficacy baseline for currently approved methods
2. Develop a technology-independent method to quantify equivalent emissions control and reduction
3. Develop a test & acceptance protocol for technology/method combinations.
4. Stakeholder preparation for the regulatory and policy adoption cycle
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Series of photos of dramatically different
methods – point sensors, aircraft, imaging, etc.
2) Define Equivalency: Assess Results in a Tech-independent Way
• Objective:• Develop method to understand performance
of dramatically different methods
• Build buy-in from stakeholders
• Concept:• Define deployment methods
• Effectiveness testing aligned methods
• Feed effectiveness metrics into software model
• Merge with company/industry processes• e.g. response process after detections
Idea is to show permanently installed
versus mobile screening, etc.
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Comparing Emissions Reduction Requires a Model
Probability of Detection
Time To Detection
Leak SizeFrequency of Leaks
Locations, etc.
Time to Correction
Probability of Recurrence
Total Emissions Probability
Solution 1Current Methods
Where Deployed
Work Practice
Detection Technology
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Shameless Advertising Alert:
OGI Baseline Study – Volunteer Your Teams!Slots open on next test week:
• October 8 – 1 team
• October 9 – 3 teams
• October 10 – 3 teams
• October 12 – 2 teams
Additional testing:
• October 23-25
• One week Tues-Thurs in early November
• Invitation• Team: Experienced camera
operator with own camera and protocol
• Operator LDAR teams
• Contractor teams
• Regulators
• Recommend 2 days on site• 5-7 surveys over 2 days
• Sponsorship from• EPA
• Environmental Partnership
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What’s New in the Solution Approaches
Deployment Protocol
• Staff training
• Usage frequency
• Data integration
• Response thresholds
…
Deployment MethodsFixed Scanning Mobile …
Sen
sor
Tech
no
logi
es
Ther
mal
Lase
r
Op
tica
l
…
Ch
emic
al
Existing types … new combinations
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Other Testing Complexities
• Technology readiness level
• Detection & quantification versus detection only
• Probabilistic outputs
• Usable reporting
… there is a >70% probability of an emissions > 10 scfh in this volume
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Current Protocols … Future Direction
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Focus of R2 Test Protocols
Deployment
• Basin Survey
• Continuous Monitoring
Repeatability
Technology Readiness
• Graded complexity: A / B / C
May June July
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Deployment Types
• Basin Survey Solutions meant for assessing multiple sites• Solution: Rapidly screen sites with mobile unit. Typically a more expensive & sensitive
system than permanent installs
• Test Design• 1 week / multiple teams
• Move between pads with different emissions scenarios “as fast as possible”
• Deployment: Mobile to site / Mobile or stationary around the site
• Continuous Monitoring – Stationary Sensors• Solution: Permanently install inexpensive sensors that operate ≈24/7
• Test Design• 2 weeks / multiple teams / larger METEC pads
• Multiple hours per emission scenario
• Deployment: Sensors at site / Sensor at a distance covering many sites
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Technology Readiness
3-Level Test Complexity
A• Single emission point per pad
• Steady emission rate
B• Multiple emission points per pad
• Steady emission rate
C• Multiple emission points per pad
• Steady, unsteady & intermittent rates
Increasing Realism
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Site ComplexitySmall Medium Large
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Reporting
• Performers reported leaks on xyz grid• GPS coordinates for automated solutions
• Human “lookup” for solutions without local GPS
• Performers varied on reporting speed• 7 MONITOR “full solutions”
• 5 Tested and returned results: Bridger, CU, PSI, IBM, Rebellion
• 1 Tested, report too late for presentation: Aeris
• 1 Hasn’t tested: PARC
• 4 non-monitor did “formal single-blind R2 tests”• Reported results: Fluke, Gas Detection, Heath/REM
• Tested, report to late for presentation: AlertPlus, Heath/REM
• @ METEC: Many additional tests that were not formal single-blind R2 tests
Recommend local-base GPS systems for future testing & SCADAintegration
• Reporting time varied from 1 week to >3 months
• Typical time – several weeks
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Detection “Grades”
• Detected• Emission point reported on same equipment unit as an emission point:
“Pad 4 / Wellhead 2”
• 15% of difficulty “C” test points had two emitters close together: Detected if one reported.
• Same Group (Important for some stationary solutions)
• Emission point reported on same equipment group as an emission point: “Pad 4 / Wellhead 2” but emission was on “Pad 4 / Wellhead 1”
• Not Detected• No reported point on same equipment or same group
• False Positive• Reported emission on equipment group with no emission point
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Not Covered in R2 Protocols
• Full complexity of emissions on real sites• Stochastic emission amounts, timing
• Long-gaps between emission events
• Operator interventions
• Weather All tests are short (max 2 weeks), all in Colorado
• Site complexity Well pads of low-to-moderate complexity
• Limited gas composition range may impact gas detection sensitivity• 86-88% methane / 10-12% ethane / market gas used for automated tests
• Methane only / unscented used for handheld tests
• No hot backgrounds
• No exhaust plumes
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Results
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Who & How Many …
• Categories are “hazy”• Several levels of “mobility” / several degrees of “stationary”
Basin SurveyContinuousMonitoring
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Complex Scenarios Are Harder …
• Detection rates drop when multiple emission points are present
• Type of multi-point emissions has less impact than “if there are multiple points”
3-Level Test Complexity
A – Single emission point per pad, Steady emission rate
B – Multiple emission points per pad, Steady emission rate
C – Multiple emission points per pad, Steady & intermittent rates
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Large, closely spaced, equipment is harder …
Some stationary solutions set up to only locate to equipment group
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Smaller Leaks are Harder …
• Handheld solutions do better – but (in theory) require more labor
• Direct confirmation of results
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Stationary Solutions – Identification Level
• Operate 24/7
• Detection is comparable to other solutions
• Localization is less precise
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Quantification remains problematic
Single point emission locationsDetected emitters only
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Localization … looks promising …
• 2D – 70% within 1 meter
• 3D – 54% within 1 meter
• Recommend automated capture of leak locations• In solution design
• In SCADA tracking systems
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Solution performance varies …
• R2 protocol is a repeatable test• Varying weather conditions … retests for
weather allowed
• No limit on time to turn in results
• Sites / hour varies substantially
• Cost of solution must also be considered• Fully automated versus “operator plus tool”
• Most drone-based require pilot now, but moving toward automated flight paths
• Mobile vehicles, drones, and handheld
• Varying degrees of automation & human intervention
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What Have We Learned?
• Testing – even in simplified METEC environment – distinguishes differences in performance
• Nuances challenge comparisons• Variation in deployment methods
• Amount of human interaction with automated solutions translates to cost
• Amount of labor in post-measurement analysis translates to cost
• Protocols are informative, but need more development • More repeat testing
• Standardized reporting – with time limits
• Tracking practical performance metrics: time/site, up-time, etc.
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Future of Testing Protocols
Proposed “Testing Products”
1. Basin survey
2. Continuous monitoringTime to detection must be measured
3. Detection only variants
4. Duration data product
Revisions & refinements of R2 protocols (with advisory input)
Basin & continuous monitoring modes for detection only solutions
Cost-reduced method to support long-term installs @ test site
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Roundup Logisitcs
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1:00 –1:40
1:50 –2:30
2:40 –3:20
3:30 –4:10
Room 1: LSC 322Tested R2 @
METEC
LongPathTechnologies, Inc.
– Basin Survey
Fluke – Basin Survey
Gas Detection Services, LLC –Basin Survey
Heath Consultants, Inc. – Basin Survey
Room 2: LSC 324Tested R2 @
METEC
Rebellion Photonics – Basin
Survey
Heath Consultants, Inc.
– Facility Monitoring
LaSen, Inc. –Basin Survey
Alert Plus, LLC –Facility
Monitoring
Room 3: LSC 350A Ballroom
No R2 METEC Test Results
MIRICO Ltd.
FLIR Systems, Inc.
United Electric Controls
MultiSensorScientific
Room 4: LSC 328-
330Tested R2 @
METEC
Bridger Photonics – Basin Survey
Remember to fill out a feedback form!
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Thank You
Contact
Daniel Zimmerle, Sr. Research Associate, Energy [email protected] | 970 581 9945
@CSUenergy
www.facebook.com/csuenergyinstutute
Energy.ColoState.edu
Thank You