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Transcript of Accutant Solutions for Shales and Tight Sands as presented atPay it Forward Network Programs...
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Rajan N. Chokshi, Ph.D.
Pay-it-Forward Network Training
Houston TX, April 7 2017
Production challenges and some solutions forproducing from Shale and Tight Reservoirs
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• How Lift applications differ for Unconventional & Tight wells Well geometries Flow behavior
• What works Field Practices & Couple of Examples
• Importance of Lift Life Cycle Planning Lift Optimization, Monitoring & Surveillance
• Conclusions
Presentation Outline
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6 out of Top 10 O&G Finds Since 2006 are Shale
Play name, CountryLocation Discovery Type Discovery
Year
Estimated
Discovery
Potential in
billion BOE/dayOnshore Offshore Oil Gas
1. Marcellus, USA X X 2006 47.0
2. Eagle Ford, USA X X X 2009 23.0
3. Libra, Brazil X X 2010 12.4
4. Buzios, Brazil X X X 2010 9.9
5. Montney, Canada X X 2007 9.4
6. Lula, Brazil X X X 2006 9.1
7. Mamba Complex, Mozambique X X 2011 8.9
8. Wolfcamp, USA X X X 2010 8.7
9. Three Forks, USA X X 2007 8.4
10. Utica, USA X X 2010 7.9
From the Houston Chronicle, “Top 10 Finds since 2006 - Most all are Shale,” Sep 08, 2016
Source: IHS Markit, 2016
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Significant Investment & Production Growth
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Images Source:https://www.linkedin.com/company-beta/572589/
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‘Ho
rizo
nta
l’W
ell
Rev
olu
tio
n
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Imp
act
of
‘Ho
rizo
nta
l’P
rod
uct
ion
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Pad
-bas
edD
rilli
ng
Data-Graphic Source:Rystad Energy Webinar, “The Reality of NorthAmerican Shale: Dark Times Now, Bright FutureAhead?“ Sept 28 2016;https://www.youtube.com/watch?v=Ak6yRpqgeLI
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Un
con
ven
tio
nal
We
lls–
Lon
gLa
tera
ls
Source: NASWELLCUBE Free, Rystad Energy, Sep 2016Source: NASWELLCUBE Free, Rystad Energy, Sep 2016
6817
11894
3892
6194 57376647
8416 9084
12637
9123 91237477
9598
0
5000
10000
15000
20000
25000
Typ
ica
lMD
,TV
D,L
ate
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en
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,ft
Typical Shale Well in Different Plays
MD TVD Lateral
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Deep, Long, Slender Well Geometry• TVD 10,000 ft
• Lateral section 5,000 ft
4" � � � � � �
5,000� � � � � � � �≅
¼" � � � � �
104 � � � � �
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Representative Shale Well Profiles
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Courtesy: Rob Sutton,Marathon Oil, 2012Courtesy: Rob Sutton,Marathon Oil, 2012
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Complex Well Geometries
11,100
11,150
11,200
11,250
11,300
11,350
11,400
0 2,000 4,000 6,000 8,000 10,000
Closure Distance, ft
Tru
eV
ert
icalD
ep
th,ft
Austin Chalk
Bakken
Barnett
Eagle Ford
Niobrara
Woodford
Utica
Complex Well Geometries
11,100
11,150
11,200
11,250
11,300
11,350
11,400
0 2,000 4,000 6,000 8,000 10,000
Closure Distance, ft
Tru
eV
ert
icalD
ep
th,ft
Austin Chalk
Bakken
Barnett
Eagle Ford
Niobrara
Woodford
Utica
Toe Up
Hybrid
Toe Down
Source: Sutton, R.: “Wellbore Geometry Effects on Well Production Performance,”SPE Liquids Rich Shale Conference, Rancho Palos Verdes, CA (May 2013).
Source: Sutton, R.: “Wellbore Geometry Effects on Well Production Performance,”SPE Liquids Rich Shale Conference, Rancho Palos Verdes, CA (May 2013).
Lateral Profiles• Toe-up well: The lateral TVD gain is
negative or the TVD at the toe is lessthan the TVD at the heel. Single Liquidaccumulation point close to heel.
• 90 Degrees perfect lateral – A Unicorn!!
• Hybrid / Undulating or “porpoising”well: Common. Many liquidaccumulation points and “A nightmarefor production operations”
• Toe-down Well: The lateral TVD gain ispositive, i.e., the TVD at the toe is morethan the TVD at the heel. Single Liquidaccumulation point farthest from thekickoff.
• Doglegs severity in ‘vertical’ or ‘deviatedsections can be significant.
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Different Flow Behaviors in Wellbore
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Flow behavior in Lateral – Changes with Trajectories
Courtesy: Tulsa Uni Horiz Well Art Lift ProjectSimulations
Courtesy: Tulsa Uni Horiz Well Art Lift ProjectSimulations
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Midland Wolfcamp Oil Well : Flow Simulation Match
Courtesy: Pipe Fraction Flow LLCCourtesy: Pipe Fraction Flow LLC
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• Pumping
• Gas-liquid separation
• Monitoring
• Back pressure
Challenges of Turbulent Flow
Well C – Eagle FordWell A – Eagle Ford
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"... ... the average decline curves for Bakken and Eagle Ford wells havenot shown significant changes since 2010. The major improvement canbe observed in the increased 24-hr initial production, but this raterapidly declines."Source: Rystad Energy: US Shale Newsletter, Vol. 1 No. 3, Jul 2014
"... ... the average decline curves for Bakken and Eagle Ford wells havenot shown significant changes since 2010. The major improvement canbe observed in the increased 24-hr initial production, but this raterapidly declines."Source: Rystad Energy: US Shale Newsletter, Vol. 1 No. 3, Jul 2014
Variable Production Rates
Well Rate Decline Curves for Shale Assets (After Rystad 2014)Well Rate Decline Curves for Shale Assets (After Rystad 2014)
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Variable Production Rates
• Steep production decline in a relatively short period.• Must plan for a wide range of production rates
• Which production systems can handle widely varyingproduction rates?• Production rate constraints – pressure maintenance, lift system
limitations (high initial rates exceed capabilities of most lift systems)
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Marcellus Shale Case Study: Gas Well Zonal Contribution
Blue zones are producing much higher than other zones. This helps operators determinethe potential value of additional well treatments including re-fracturing. Blue zones are producing much higher than other zones. This helps operators determinethe potential value of additional well treatments including re-fracturing.Source: Gonzalez, L. E., Chokshi, R. N., & Lane, W. (2015, August 4). Importance of Downhole Measurements,
Visualization and Analysis in Producing Unconventional Wells. SPE. doi:10.15530/urtec-2015-2164102Source: Gonzalez, L. E., Chokshi, R. N., & Lane, W. (2015, August 4). Importance of Downhole Measurements,
Visualization and Analysis in Producing Unconventional Wells. SPE. doi:10.15530/urtec-2015-2164102
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1. Well Depth & Geometry Deep, long, slender well geometries.
Cost of interventions
Transient mixed phase sluggy and turbulent flow.
2. Ultra-low Permeability Steep & rapid production decline
Production rate constraints
Mixed phase flow
3. Uncertain zonal contribution.
4. Gas, Sand, paraffin, scale, corrosion
5. Operations, power supply, surface facilities, location access
Production Challenges in Shale & Tight Reservoirs
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• Choke the production rate Increases EUR. Reduces possibility of permeability-loss in over-pressured formation.
SPE 147623 on Haynesville Shale modeling: “… a restricted well has higher productivity than anunrestricted well producing in the same field. … this difference can be quantified by the behaviorof the permeability decay function.”
Higher FTHP delays need for artificial lift systems.
Increased FBHP delays gas breakout might reduce pooling in the lateral traps
• Maintain adequate liquid levels 200 ft above liner top
75 to 100 ft above pump.
Early Production
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• Mechanical pumps can pump from low spots but are not effective in“sweeping” liquids through laterals.
• Mechanical pumps can have gas interference issues.▫ Gas anchors are required in gassy wells.
• Where possible, land mechanical pumps:▫ In vertical section 50 to 100 ft above the liner top▫ In straight sections if within the deviated section
• Use continuous lift optimization (surveillance, analysis, prioritizing,adjustment)
Lessons – Deliquifying Laterals
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Well Life Cycle Rate (BPD) Gas Lift ESP Jet PumpPistonPump
RodPump
PlungerLift
CapFoam
Frac-Flowback 500 ()
Initial high rates 500 ()
Medium liquid rates <500
Low liquid rates <200
Summary – Typical Use of Artificial Lift in Shale Plays
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• Need to think about Artificial Lift before Well is onPaper
• Involve production/operations during the well design.
▫ Toe up orientation if possible.
▫ ‘Rat hole’ for better gas separation???
▫ Control tortuosity of horizontal section of well - Minimize undulations/traps
▫ Intentionally plan/control vertical transition to horizontal section
▫ Will casing geometries permit sufficiently sized ALS technology in future?
Importance of Integrated Planning
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Gas Lift
Wel
lPre
par
atio
n-
FFR
Wel
lPre
par
atio
n-
FFR
Jet Pump
ESP
Rod Pump
Hydraulic Piston Pump
Plunger Lift
Foam
Lift Life Cycle Planning
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Hybrid Completion: JP → GL
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SOLUTIONSREQUIREMENTSCHALLENGE
Importance of Monitoring & Surveillance
Rapidly declining orfluctuatingproduction
Real-time continuouslift & adjustments
Well-site flow rateand downhole P/T
Changing inflowphases and zonal
contribution
Visibility of what ishappening
Optimization of fieldresources (injection,service crews, rigs…)
Organized schedulingof limited assets
Surveillance andanalysis software
Field managementdatabase & software
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• Accurate and timely monitoring is critical for production management andoptimization.▫ Tracer chemicals for initial inflow▫ Production logging for snapshot of transients Sporadic measurements are not adequate for managing dynamic production.
• Permanent downhole gage systems provide continuous real-time visibility ofproduction conditions.▫ Artificial lift status▫ P, T, Q▫ Zonal contribution
• Data visualization and analysis software simplify production management andoptimization.
Surveillance & Monitoring
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Continuoushigh granularitymeasurementsrevealed slugs
Case: Permanent Electronic Gauges – Shale Rod Pumping
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Source: Gonzalez, L. E., Chokshi, R. N., & Lane, W. C. (2015, October 20). Real-Time Surface and Downhole Measurements and Analysis for Optimizing Production.Society of Petroleum Engineers. doi:10.2118/176233-MSSource: Gonzalez, L. E., Chokshi, R. N., & Lane, W. C. (2015, October 20). Real-Time Surface and Downhole Measurements and Analysis for Optimizing Production.Society of Petroleum Engineers. doi:10.2118/176233-MS
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Case: Accurate Flow Measurements in Shale
Well C – Eagle Ford
Well A – Eagle Ford
Source: WeatherfordSource: Weatherford
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• How are artificial lift applications different forunconventional & tight wells?
▫ Well geometries pose production challenges
▫ Understanding of flow behavior is very important and stilldeveloping.
Conclusions
Additional References1. Lane, W., & Chokshi, R. (2014, August 28). Considerations for Optimizing Artificial Lift in Unconventionals. SPE.
doi:10.15530/urtec-2014-1921823.2. Gonzalez, L. E., Chokshi, R. N., & Lane, W. (2015, August 4). Importance of Downhole Measurements, Visualization
and Analysis in Producing Unconventional Wells. SPE. doi:10.15530/urtec-2015-2164102
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•What needs to be done?▫ Involve production & operations during well design
Toe Up.... Avoid Traps in Lateral
▫ Select flexible lift systems Stay current on what works where and why.
▫ Think in terms of the lift life cycle You will need to change to another lift – sooner or later...
▫ Include Lift Monitoring & Surveillance from the beginning Surface Flow and downhole P/T measurements add considerable value to the overall production
optimization and recovery.
Conclusions
Additional References1. Lane, W., & Chokshi, R. (2014, August 28). Considerations for Optimizing Artificial Lift in Unconventionals. SPE.
doi:10.15530/urtec-2014-1921823.2. Gonzalez, L. E., Chokshi, R. N., & Lane, W. (2015, August 4). Importance of Downhole Measurements, Visualization
and Analysis in Producing Unconventional Wells. SPE. doi:10.15530/urtec-2015-2164102
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Questions, Discussion
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