Capstone Project Presentation final final
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Transcript of Capstone Project Presentation final final
Petroleum Industry Project
Hydraulic Fracturing Optimization using Chemical Tracer
Kailash Chhetri
Agenda
Overview of Canbriam Energy Inc.
Objective and Scope
Canbriam Completion Design
Frac Techniques & Diagnostic tool
Data Sources
Analysis of Data
Conclusion and Recommendations
Canbriam Energy Inc.
Private E&P company operating in
Northeastern B.C
Targets Montney Formation
40 producing wells, 2 operating
gas plants
Facility capacity of 130 MMCF/day
3 rigs active drilling 4 well pads
Current production ~18,500
boe/day (~20% liquids)
2014 production 9500 boe/day
(20 % liquids)Source: Canbriam corporate presentation March 2015
Location & Field Information
Over pressured siltstone/shale reservoir
Montney split – Upper, Middle & Lower
Canbriam’s all wells – Upper & Lower
Montney
Drilled horizontally – reservoir exposure
Major players – Progress, Shell, Encana,
etc.
Source: Canbriam corporate presentation March 2015
Objective
Collect data from wells with Chemical Tracer
Analyze & compare with frac properties & methods
Evaluate contribution of well flowback given by
each stage
Evaluate properties that have positive or negative
effects on flowback
Identify areas of optimization for Canbriam frac
design
Scope
Limited to Canbriam’s Hz Montney wells Stimulated using plug & perf and
slickwater frac techniques
Data Frac summaries from Canyon Tracer reports from ProTechnics
Canbriam Completion Design
Canbriam’s completion design parameters: Perf spacing
Clusters per stage
Number of Stages
Stage length
Tonnage per stage
Target rates Target
concentrations
Source: Canbriam corporate presentation Oct. 2014
Frac Techniques & Diagnostic tool
TechniquesPlug & perfSlickwater frac
Diagnostic toolChemical Tracer
Normalized Data Table-CFT(ppb)
Traced Segment 17-13 12-9 8-5 4-1
Stim Date 7/21/13 7/20/13 7/19/13 7/18/13 Totals Avgs
Traced Fluid vol (m3) 4,646 3,526 3,972 3,342 15,486 3,872
CFT Injected (g) 3,682 2,522 2,927 2,499 11,630 2,908
% Injected 31.7% 21.7% 25.2% 21.5%
Key Cum Vol* Sample Date Sample Type CFT 2500 CFT 2400 CFT 2200 CFT 2100CFT Total
ppb
Calc Chlorides
Total
>200 1 74.4 8/2/13 12:00 Water (Produced) 65.6 47.6 30.4 0.0 143.6 59,025150 to 200 2 203.2 8/2/13 20:00 Water (Produced) 83.8 52.2 16.4 0.5 152.8 59,168100 to 150 3 340.1 8/3/13 12:00 Water (Produced) 16.0 28.2 24.4 116.8 185.4 53,49470 to 100 4 475.8 8/3/13 20:00 Water (Produced) 42.0 37.0 20.6 55.5 155.0 56,48450 to 70 5 668.2 8/4/13 8:00 Water (Produced) 48.0 39.3 21.7 49.9 158.9 60,874
35 to 50 6 849.6 8/4/13 20:00 Water (Produced) 41.7 30.2 15.7 42.4 130.0 60,15725 to 35 7 927.0 8/5/13 8:00 Water (Produced) 47.1 30.3 14.5 43.6 135.6 58,56017 to 25 8 1624.9 8/23/13 3:00 Water (Produced) 36.3 23.2 10.9 24.7 95.2 73,33812 to 17 9 1732.6 8/25/13 0:01 Water (Produced) 30.9 19.7 9.1 15.3 74.9 77,3778 to 12 10 1857.5 8/27/13 18:30 Water (Produced) 37.3 21.0 9.2 18.3 85.8 75,9615 to 8 11 1926.0 8/28/13 18:30 Water (Produced) 33.9 18.4 8.4 19.5 80.2 76,9343 to 5 12 2032.5 8/30/13 6:30 Water (Produced) 31.9 20.5 8.0 18.7 79.1 79,980
2 to 3 13 2134.2 9/2/13 15:00 Water (Produced) 30.2 22.0 9.0 17.9 79.2 91,7321 to 2 14 2169.0 9/4/13 17:30 Water (Produced) 27.8 20.8 8.6 16.5 73.7 95,108
0.05 to 1 15 2205.0 9/6/13 18:30 Water (Produced) 25.9 19.5 8.0 15.5 68.9 91,923
16 2240.0 9/8/13 18:30 Water (Produced) 29.7 22.8 9.2 18.0 79.7 96,79717 2293.0 9/11/13 18:30 Water (Produced) 26.8 20.4 8.0 16.0 71.2 100,156
18 4379.9 5/27/14 0:00 Water (Produced) 11.2 6.0 3.4 6.0 26.6 87,885
19 6739.3 1/28/15 8:53 Water (Produced) 1.6 0.8 0.9 11.4 14.7 52,35820 6744.7 1/28/15 18:30 Water (Produced) 2.7 1.5 0.5 10.3 15.0 61,12021 6755.5 1/29/15 14:20 Water (Produced) 4.8 2.8 1.0 10.1 18.6 91,695
12 Time Weighted Avg ppb 8.5 4.9 2.8 9.7 25.9 71,209Avg M3D % total ppb from Stage 32.8% 18.8% 10.8% 37.6% 100.0%
% total ppb @ last sample 25.6% 14.9% 5.4% 54.1% 100.0%Mass Balance Recov'd (g) 149.0 68.4 41.7 97.0 356.1
% of Total Recovery 41.8% 19.2% 11.7% 27.2% 100.0%SLR 10.0 7.4 4.3 10.0 7.9
No Flow Zones 0 0 DeductHeel/Toe Ratio 0.9 0 Deduct
14 Day flow decline 44% 0 DeductTraced Fluid Recovered 3.1%
Normalized Chemical Frac Tracer, ppb
FPE 7.9
Canbriam Energy, Inc. c-B27-H/94-B-8 Normalized Data Table
Source: Spectra Chem, Initial Flowback report
Data and its Source
Well & Perf data : Well Name, Stage, Perf
cluster, etc.
Canbriam well completion DR file
Frac properties : Pressure ,Sand amount, Fluid
volume
Canyon Technical Services
Chemical Frac Tracer concentration flow back
ProTechincs
Data Selection
Started with 13 wells
Chance-Study, compare, analyze & collect
viable data
Came down to 10 wells
3 initial wells- no enough data
Finally picked 6 wells
Good representation sample for study
Limited time
Well Data & Frac properties
Note: This is a partial data. Data for 6 wells that had minimum 8 stages and maximum 17 stages
WELL DATAFRAC PROPERTIES
PERF DATA PRESSURE SAND FLUID
Well Name Stage Start Date Top (mKB)
Bottom (mKB)
Stage Length (m)
Perf Spacing (m) SPM Perf Clusters Breakdown
(MPA)Avg Pressure
(MPA) ISIP (MPA) Tonnage TPM Max
Concentration (kg/m3)
Avg Rate (m3/min)
Max Rate (m3/min)
Rate per Perf (m3/min)
Clean Volume (m3)
c-B27-H/94-B-8 1 July 18, 2013 4495 4600 105 30 12 4 50.6 54.8 31 121.6 1.16 358 7.6 8.9 1.9 911.2
c-B27-H/94-B-8 2 July 18, 2013 4375 4495 120 30 12 4 57.3 56 30.7 120.5 1.00 363 8.9 9.1 2.2 883.0
c-B27-H/94-B-8 3 July 19, 2013 4255 4375 120 30 12 4 62.6 57 31.8 120.2 1.00 355 8.2 8.5 2.1 854.3
c-B27-H/94-B-8 4 July 19, 2013 4135 4255 120 30 12 4 59.9 56 31.9 124 1.03 359 6.9 8.5 1.7 920.2
c-B27-H/94-B-8 5 July 19, 2013 4015 4135 120 30 12 4 60 56 31.5 120.6 1.01 336 7.0 8.7 1.8 909.0
c-B27-H/94-B-8 6 July 19, 2013 3895 4015 120 30 12 4 60 57 32 120.3 1.00 356 6.2 9.1 1.6 809.1
c-B27-H/94-B-8 7 July 19, 2013 3745 3895 150 30 12 5 58.6 57.5 33 148.8 0.99 355 8.4 9.2 1.7 1005.6
c-B27-H/94-B-8 8 July 20, 2013 3595 3745 150 30 12 5 57.9 57 32.5 165.9 1.11 287 7.7 9.3 1.5 1544.2
c-B27-H/94-B-8 9 July 20, 2013 3475 3595 120 30 12 4 59 57 32.9 142.8 1.19 364 7.6 9.3 1.9 1074.4
c-B27-H/94-B-8 10 July 20, 2013 3355 3475 120 30 12 4 51 57 32.8 120.9 1.01 358 8.6 9.5 2.2 794.1
c-B27-H/94-B-8 11 July 21, 2013 3235 3355 120 30 12 4 50.3 57 32 119.9 1.00 359 9.3 9.8 2.3 788.8
c-B27-H/94-B-8 12 July 21, 2013 3085 3235 150 30 12 5 52.6 57.3 32.1 150.8 1.01 382 10.0 10.7 2.0 971.4
c-B27-H/94-B-8 13 July 21, 2013 2935 3085 150 30 12 5 50.8 57 31.4 150.2 1.00 330 8.7 10.4 1.7 981.7
c-B27-H/94-B-8 14 July 21, 2013 2785 2935 150 30 12 5 51 57 31.9 150.4 1.00 354 8.8 10.3 1.8 1007.5
c-B27-H/94-B-8 15 July 21, 2013 2635 2785 150 30 12 5 53 57.5 32 150.9 1.01 354 10.0 10.5 2.0 1100.2
c-B27-H/94-B-8 16 July 22, 2013 2515 2635 120 30 12 4 55 57 32.2 120.6 1.01 352 10.6 11.0 2.6 831.0
c-B27-H/94-B-8 17 July 22, 2013 2410 2515 105 30 12 4 50.2 58 32.8 119.8 1.14 359 10.6 10.7 2.7 789.0
Source: Canbriam Daily well completion report
Data- Chemical Tracer flowback(ppb)
TRACER
Tracer
Day
1 2 3 4 5 10 15 20 25 30 35 40 45 50 55 60
CFT2100 0 0.5 116.8 55.5 49.9 42.4 43.6 24.7 15.3 18.3 19.5 18.7 17.9 16.5 15.5 18.0
CFT2100 0 0.5 116.8 55.5 49.9 42.4 43.6 24.7 15.3 18.3 19.5 18.7 17.9 16.5 15.5 18.0
CFT2100 0 0.5 116.8 55.5 49.9 42.4 43.6 24.7 15.3 18.3 19.5 18.7 17.9 16.5 15.5 18.0
CFT2100 0 0.5 116.8 55.5 49.9 42.4 43.6 24.7 15.3 18.3 19.5 18.7 17.9 16.5 15.5 18.0
CFT2200 30.4 16.4 24.4 20.6 21.7 15.7 14.5 10.9 9.1 9.2 8.4 8.0 9.0 8.6 8.0 9.2
CFT2200 30.4 16.4 24.4 20.6 21.7 15.7 14.5 10.9 9.1 9.2 8.4 8.0 9.0 8.6 8.0 9.2
CFT2200 30.4 16.4 24.4 20.6 21.7 15.7 14.5 10.9 9.1 9.2 8.4 8.0 9.0 8.6 8.0 9.2
CFT2200 30.4 16.4 24.4 20.6 21.7 15.7 14.5 10.9 9.1 9.2 8.4 8.0 9.0 8.6 8.0 9.2
CFT2400 47.6 52.2 28.2 37 39.3 30.2 30.3 23.2 19.7 21.0 18.4 20.5 22.0 20.8 19.5 22.8CFT2400 47.6 52.2 28.2 37 39.3 30.2 30.3 23.2 19.7 21.0 18.4 20.5 22.0 20.8 19.5 22.8
CFT2400 47.6 52.2 28.2 37 39.3 30.2 30.3 23.2 19.7 21.0 18.4 20.5 22.0 20.8 19.5 22.8
CFT2400 47.6 52.2 28.2 37 39.3 30.2 30.3 23.2 19.7 21.0 18.4 20.5 22.0 20.8 19.5 22.8
CFT2500 65.6 83.8 16 42 18 41.7 36.3 30.9 37.3 33.9 31.9 30.2 27.8 25.9 29.7 26.8
CFT2500 65.6 83.8 16 42 18 41.7 36.3 30.9 37.3 33.9 31.9 30.2 27.8 25.9 29.7 26.8
CFT2500 65.6 83.8 16 42 18 41.7 36.3 30.9 37.3 33.9 31.9 30.2 27.8 25.9 29.7 26.8
CFT2500 65.6 83.8 16 42 18 41.7 36.3 30.9 37.3 33.9 31.9 30.2 27.8 25.9 29.7 26.8
CFT2500 65.6 83.8 16 42 18 41.7 36.3 30.9 37.3 33.9 31.9 30.2 27.8 25.9 29.7 26.8
Note: Similar CFT flowback concentration data collected for 6 wells
Source: Canbriam Energy Well-Normalized data table
Analysis
Frac properties vs CFT flowback Maximum Concentration (Kg/m3) Total tonnage(T) Tonnage per meter Average rate (m3/min) Maximum rate (m3/min) Rate per perf (m3/min) Clean volume (m3) Average treating pressure (Mpa) Initial shut in pressure (Mpa)
Maximum sand concentration(Kg/m3) vs Time/CFT
310.0
320.0
330.0
340.0
350.0
360.0
370.0
0
20
40
60
80
100
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17
Max
Conc
entra
tion((
kg/m
3)
CFT F
lowba
ck (p
pb)
Stages
Maximum Concentration(Kg/m3) vs CFT Flowback5 days30 days60 daysMax Concentration
Max Concentration vs Time Max Concentration vs CFT Flowback
Source: Canyon Technical Services frac summary report
Tonnage(T) vs CFT Concentration flowback(ppb)
Total Tonnage vs CFT flowback
Tonnage per Meter vs CFT flowback
Rate(m3/min) vs CFT Concentration(ppb) flowback
Average rate(m3/min) vs CFT concentration(ppb)
Rate per perf (m3/min) vs CFT
concentration(ppb)
Conclusion
Found strong correlation between sand
concentration & CFT flowback
Higher sand concentration contributed best
production performance
Worst wells were with most water volume used in
completions
More contribution by tonnes per meter than total
tonnage
Recommendations
Maximize target sand concentration for higher
flowback
Optimize the number of perf clusters to obtain
better production rate
Increase tonnage per meter to improve stages
conductivity and higher deliverability
Reduce the length of stage as it increases TPM &
SRV
Questions?
Thank you!
Acknowledgements
Graham Janega, MentorMr. Clay Howe, TechnologistAdrian McFarlane, Advisor