This document summarizes a study evaluating completion effectiveness in horizontal multi-stage fractured wells in the Pembina Cardium field. It reviews production metrics like maximum oil rate and cumulative oil after 1 year to assess completion performance. Case studies of 2006-2009 and 2014 wells show early wells were affected by offsetting waterfloods while later wells remained in linear flow for over 1 year. Cumulative oil after 365 days normalized by number of stages was selected as the production metric. A comparison of different treatment fluids found slickwater was suboptimal, while polyemulsions and foams had the best performance based on normalized cumulative oil and completion costs. Proppant concentration may impact gas well performance but is less important than fracture length for
Field Development Project : Gelama MerahHami Asma'i
A green field development project located in Sabah Basin comprises the whole upstream field development cycle from geology, reservoir studies to production facilities and economics. The objective is to come out with the best strategy to develop the field starting from our very own effort of reservoir characterization out of log and core data. Under supervision of lecturers, this project was completed as per scheduled.
Among new technical methodologies applied upon the completion this project:
1. Cubic Spline Interpolation Method in bulk volume calculation
2. Monte Carlo probabilistic method in reserve estimation
3. Reservoir Opportunity Index (ROI) method in well placement
Project was assessed by PETRONAS custodians.
We are all familiar with the production systems through which reservoir fluids flow to reach our processing facilities. This is a journey characterized by complex multiphase flow phenomena that govern pressure and temperature changes along the way. A monumental amount of research and development work has been invested towards better understanding multiphase flow behavior over the past fifty years. Yet, many challenges remain as we strive to optimize ever more complex production systems fraught with difficult flow assurance issues. Just how good is the science? And more importantly, how does this impact our bottom line? This lecture will discuss key concepts of multiphase flow leading to the current “state-of-the-art” models used today. Looking towards the future, the science must be advanced to address areas of greatest uncertainty and align with trends in field development strategies. Recommendations will be presented covering the top 5 areas of research necessary for these purposes. The economic impact of multiphase operations will be illustrated using two examples that provide insight towards maximizing asset value.
Mack Shippen is a Principal Engineer with Schlumberger in Houston, where he is responsible for the global business of the PIPESIM multiphase flow simulation software. He has extensive experience in well and network simulation studies, ranging from flow assurance to dynamic coupling of reservoir and surface simulation models. He has served on a number of SPE committees and chaired the SPE Reprint Series on Offshore Multiphase Production Operations. He holds BS and MS degrees in Petroleum Engineering from Texas A&M University, where his research focused on multiphase flow modelling.
Production Optimization using nodal analysis. The nodal systems analysis approach is a very flexible method
that can be used to improve the performance of many well
systems. The nodal systems analysis approach may be used to analyze
many producing oil and gas well problems. The procedure can
be applied to both flowing and artificial
Field Development Project : Gelama MerahHami Asma'i
A green field development project located in Sabah Basin comprises the whole upstream field development cycle from geology, reservoir studies to production facilities and economics. The objective is to come out with the best strategy to develop the field starting from our very own effort of reservoir characterization out of log and core data. Under supervision of lecturers, this project was completed as per scheduled.
Among new technical methodologies applied upon the completion this project:
1. Cubic Spline Interpolation Method in bulk volume calculation
2. Monte Carlo probabilistic method in reserve estimation
3. Reservoir Opportunity Index (ROI) method in well placement
Project was assessed by PETRONAS custodians.
We are all familiar with the production systems through which reservoir fluids flow to reach our processing facilities. This is a journey characterized by complex multiphase flow phenomena that govern pressure and temperature changes along the way. A monumental amount of research and development work has been invested towards better understanding multiphase flow behavior over the past fifty years. Yet, many challenges remain as we strive to optimize ever more complex production systems fraught with difficult flow assurance issues. Just how good is the science? And more importantly, how does this impact our bottom line? This lecture will discuss key concepts of multiphase flow leading to the current “state-of-the-art” models used today. Looking towards the future, the science must be advanced to address areas of greatest uncertainty and align with trends in field development strategies. Recommendations will be presented covering the top 5 areas of research necessary for these purposes. The economic impact of multiphase operations will be illustrated using two examples that provide insight towards maximizing asset value.
Mack Shippen is a Principal Engineer with Schlumberger in Houston, where he is responsible for the global business of the PIPESIM multiphase flow simulation software. He has extensive experience in well and network simulation studies, ranging from flow assurance to dynamic coupling of reservoir and surface simulation models. He has served on a number of SPE committees and chaired the SPE Reprint Series on Offshore Multiphase Production Operations. He holds BS and MS degrees in Petroleum Engineering from Texas A&M University, where his research focused on multiphase flow modelling.
Production Optimization using nodal analysis. The nodal systems analysis approach is a very flexible method
that can be used to improve the performance of many well
systems. The nodal systems analysis approach may be used to analyze
many producing oil and gas well problems. The procedure can
be applied to both flowing and artificial
Why Frac & How it works!
Rock Mechanics
Fundamentals of Hydraulic Fracturing
Fracturing models
Design criteria for frac treatments
Frac Equipment
Frac chemicals and proppants
QC for Frac job
Hydraulic fracturing technologies and practices
This presentation is intended to compare the manual and computerized calculation. This software can be customized for any fuel carrying barge requiring LIST and TRIM correction. It can also be usable to manage the fuel storage system in any Tank Firm.
This software is designed for Marine Bunker Surveyors to minimize time in bunker quantification following API-MPMS guidelines. It also contains some other conversion tools which are really important to calculate the fuel characteristics like Shell CCAI, BP CII, Net and Gross Specific Energy, Injection, Temperature based on measured viscosity, density conversion tools and much more.
The well was constructed at 2913 Union Ave, Las Cruces, NM 88005. A grain size distribution was graphed according to the data collected from the sieve analysis test and screening area was determined as well as the minimum length of screen “Ls”. The hydraulic conductivity was calculated using a falling head test. A pump and a motor were chosen according to the manual sent from the professor. The cost was measured in “$/A.F.” from the calculated data.
Over the past few years, significant advancements have been made in completion and stimulation designs in horizontal wells in unconventional plays, with the primary driver being the improvement of fracture contact area in these very low permeability reservoirs, to improve production volumes and recoveries. Fracture contact area with plug-and-perf or sliding sleeve systems have been intensified by increasing the density of contact points in the formation as well as proppant amount with great success. While these parameters have been optimized, other important parameters such as fracture conductivity and connectivity have been largely neglected. In the journey to improving contact area, proppant conductivity is often sacrified to save costs, and fracture stimulation treatments are overflushed in order to maximize operational efficiencies on multi-well pads. This presentation will highlight the importance of all of these parameters, and provides steps that can be taken to further optimize and enhance well producitivity and economics in the shale plays.
Oil & Gas Pipelines are often subjected to an operation called ‘Pigging’ for maintenance purposes (For e.g., cleaning the pipeline of accumulated liquids or waxes). A pig is launched from a pig launcher that scrapes out the remnant contents of the pipeline into a vessel known as a ‘Slug catcher’. The term slug catcher is used since pigging operations produces a Slug flow regime characterized by the alternating columns of liquids & gases. Slug catcher’s are popularly of two types – Horizontal Vessel Type & Finger Type Slug catcher. However irrespective of the type used, the determination of the slug catcher volume becomes the primary step before choosing the slug catcher type.
An effective reservoir management by streamline based simulation, history mat...Shusei Tanaka
The use of the streamline-based method for reservoir management is receiving increased interest in recent years because of its computational advantages and intuitive appeal for reservoir simulation, history matching and rate allocation optimization. Streamline-based method uses snapshots of flow path of convective flow. Previous studies proved its applicability for convection dominated process such as waterflooding and tracer transport. However, for a case with gas injection with strong capillarity and gravity effects, the streamline-based method tends to lose its advantages for reservoir simulation and may result in loss of accuracy and applicability for history-matching and optimization problems.
In this study, we first present the development of a 3D 3-phase black oil and compositional streamline simulator. Then, we introduce a novel approach to incorporate capillary and gravity effects via orthogonal projection method. The novel aspect of our approach is the ability to incorporate transverse effects into streamline simulation without adversely affecting its computational efficiency. We demonstrate our proposed method for various cases, including CO2 injection scenario. The streamline model is shown to be particularly effective to examine and visualize the interactions between heterogeneity which resulting impact on the vertical and areal sweep efficiencies.
Next, we apply the streamline simulator to history matching and rate optimization problems. In the conventional approach of streamline-based history matching, the objective is to match flow rate history, assuming that reservoir energy was matched already, such as pressure distribution. The proposed approach incorporates pressure information as well as production flow rates, aiming that reservoir energy are also reproduced during production rate matching.
Finally, we develop an NPV-based optimization method using streamline-based rate reallocation algorithm. The NPV is calculated along streamline and used to generate diagnostic plots of the effectiveness of wells. The rate is updated to maximize the field NPV. The proposed approach avoids the use of complex optimization tools. Instead, we emphasize the visual and the intuitive appeal of streamline methods and utilize flow diagnostic plots for optimal rate allocation.
We concluded that our proposed approach of streamline-based simulation, inversion and optimization algorithm improves computational efficiency and accuracy of the solution, which leads to a highly effective reservoir management tool that satisfies industry demands.
Water Injection & Treatment for Tight Oil EOR
EOR choices for light Tight Oil
Potential damage to reservoir and well bore.
Water Specifications & Treatment
Case Studies:
1. Advanced Water Flooding
2. Frac injectors?
3. Low Salinity Water Flooding
Topics Include:
Filtration
Water Quality
Reservoir Pressure
Why Frac & How it works!
Rock Mechanics
Fundamentals of Hydraulic Fracturing
Fracturing models
Design criteria for frac treatments
Frac Equipment
Frac chemicals and proppants
QC for Frac job
Hydraulic fracturing technologies and practices
This presentation is intended to compare the manual and computerized calculation. This software can be customized for any fuel carrying barge requiring LIST and TRIM correction. It can also be usable to manage the fuel storage system in any Tank Firm.
This software is designed for Marine Bunker Surveyors to minimize time in bunker quantification following API-MPMS guidelines. It also contains some other conversion tools which are really important to calculate the fuel characteristics like Shell CCAI, BP CII, Net and Gross Specific Energy, Injection, Temperature based on measured viscosity, density conversion tools and much more.
The well was constructed at 2913 Union Ave, Las Cruces, NM 88005. A grain size distribution was graphed according to the data collected from the sieve analysis test and screening area was determined as well as the minimum length of screen “Ls”. The hydraulic conductivity was calculated using a falling head test. A pump and a motor were chosen according to the manual sent from the professor. The cost was measured in “$/A.F.” from the calculated data.
Over the past few years, significant advancements have been made in completion and stimulation designs in horizontal wells in unconventional plays, with the primary driver being the improvement of fracture contact area in these very low permeability reservoirs, to improve production volumes and recoveries. Fracture contact area with plug-and-perf or sliding sleeve systems have been intensified by increasing the density of contact points in the formation as well as proppant amount with great success. While these parameters have been optimized, other important parameters such as fracture conductivity and connectivity have been largely neglected. In the journey to improving contact area, proppant conductivity is often sacrified to save costs, and fracture stimulation treatments are overflushed in order to maximize operational efficiencies on multi-well pads. This presentation will highlight the importance of all of these parameters, and provides steps that can be taken to further optimize and enhance well producitivity and economics in the shale plays.
Oil & Gas Pipelines are often subjected to an operation called ‘Pigging’ for maintenance purposes (For e.g., cleaning the pipeline of accumulated liquids or waxes). A pig is launched from a pig launcher that scrapes out the remnant contents of the pipeline into a vessel known as a ‘Slug catcher’. The term slug catcher is used since pigging operations produces a Slug flow regime characterized by the alternating columns of liquids & gases. Slug catcher’s are popularly of two types – Horizontal Vessel Type & Finger Type Slug catcher. However irrespective of the type used, the determination of the slug catcher volume becomes the primary step before choosing the slug catcher type.
An effective reservoir management by streamline based simulation, history mat...Shusei Tanaka
The use of the streamline-based method for reservoir management is receiving increased interest in recent years because of its computational advantages and intuitive appeal for reservoir simulation, history matching and rate allocation optimization. Streamline-based method uses snapshots of flow path of convective flow. Previous studies proved its applicability for convection dominated process such as waterflooding and tracer transport. However, for a case with gas injection with strong capillarity and gravity effects, the streamline-based method tends to lose its advantages for reservoir simulation and may result in loss of accuracy and applicability for history-matching and optimization problems.
In this study, we first present the development of a 3D 3-phase black oil and compositional streamline simulator. Then, we introduce a novel approach to incorporate capillary and gravity effects via orthogonal projection method. The novel aspect of our approach is the ability to incorporate transverse effects into streamline simulation without adversely affecting its computational efficiency. We demonstrate our proposed method for various cases, including CO2 injection scenario. The streamline model is shown to be particularly effective to examine and visualize the interactions between heterogeneity which resulting impact on the vertical and areal sweep efficiencies.
Next, we apply the streamline simulator to history matching and rate optimization problems. In the conventional approach of streamline-based history matching, the objective is to match flow rate history, assuming that reservoir energy was matched already, such as pressure distribution. The proposed approach incorporates pressure information as well as production flow rates, aiming that reservoir energy are also reproduced during production rate matching.
Finally, we develop an NPV-based optimization method using streamline-based rate reallocation algorithm. The NPV is calculated along streamline and used to generate diagnostic plots of the effectiveness of wells. The rate is updated to maximize the field NPV. The proposed approach avoids the use of complex optimization tools. Instead, we emphasize the visual and the intuitive appeal of streamline methods and utilize flow diagnostic plots for optimal rate allocation.
We concluded that our proposed approach of streamline-based simulation, inversion and optimization algorithm improves computational efficiency and accuracy of the solution, which leads to a highly effective reservoir management tool that satisfies industry demands.
Water Injection & Treatment for Tight Oil EOR
EOR choices for light Tight Oil
Potential damage to reservoir and well bore.
Water Specifications & Treatment
Case Studies:
1. Advanced Water Flooding
2. Frac injectors?
3. Low Salinity Water Flooding
Topics Include:
Filtration
Water Quality
Reservoir Pressure
Upstream business in tough condition but future development still promising. Re-entry drilling using hydraulic work over unit in offshore mature filed will viable in economic point of view.
While America as a whole is undergoing a 'shale oil boom', the question that remains is "what do operators need to do to make it happen in California?"
The Department of Energy has estimated that the Monterey shale contains 15 billion barrels of oil - more than the Bakken and Eagle Ford shales collectively. This, combined with a mean of 6.5 billion barrels in San Joaquin fields such as the Kern River, Elk Hills, Midway-Sunset and Belridge South, around 1 million barrels in the Santa Maria basin, means California literally has the potential to become the most prolific oil resource within the US.
To fully exploit the Monterey and surrounding unconventional resources within California, the structural and lithological complexity of shale and diatomite reservoirs needs to be further understood to enable the identification of stimulation technologies that will maximize oil recovery, whether it be acid fracturing, hydraulic fracturing or steam injection.
The Tight Oil Reservoirs California 2014 Congress is the only E&P led congress with a specific focus on optimizing recovery in unconventional reservoirs within California. Leading E&P companies from the Monterey, Kreyenhagen and wider San Joaquin, Santa Maria and LA Basins will showcase optimized logging suites and seismic technologies to obtain key petrophysical, geomechanical and lithological data of California's sediments to finally be able to commercially exploit shale and to increase return on investment within diatomite.
Considering the sensitive nature of the current regulatory environment, strategies for complying with SB4 and AB32 and expediting hydraulic fracturing and steam injection permit approvals will be also examined. Finally, speakers will discuss case studies on how to source, transport and recycle water to ensure compliance with state regulations while minimizing operational costs within California.
Larry Shultz presents TexasEOR.com Exhaust Gas Injection CO2 Enhanced Oil Rec...Larry Shultz
Why spend >$50-$60 to produce a barrel of shale/tight oil, when new portable exhaust gas injection EOR equipment has the potential to recover oil for less than $15-$25 per barrel?
Fielding the oil industry’s next-generation fleet of fully-automated, portable exhaust gas injection N2+CO2 EOR skids to bring low-cost, variable-pressure gas injection EOR capabilities on-site to EOR-worthy mature and legacy oil fields that are too far away from and cannot be economically served by CO2 pipelines.
In all markets, the online classifieds segment is highly competitive. The advertiser has significantly more choice than they did in the past. There are dedicated vertical sites (for cars, jobs and homes) as well as general classifieds sites (horizontal) that service all markets. Is this a winner take all market or is there room for both horizontal and vertical players. Simon Baker, the Chairman of the Mitula Group and former CEO/MD of the REA Group in Australia, will discuss what the likely outcome is by looking at what is happing in the highly competitive online real estate segment.
Review of EOR Selection for light tight oil
Key Themes:
Upfront EOR Development Planning
Cash is king but Permeability Rules
Geology Selects Technology
Nanospheres, Steam Flooding, Misc Gas Flooding, EOR Selection Criteria
Enhanced Oil Recovery
It’s a process for recovering mostly every Barrels of Oil to get out all of remaining oil in it.
And this is done by EOR technologies
Enhanced Oil Recovery
Mainly the following process are done for Enhanced oil recovery
Water injection
Gas injection
Reducing residual oil saturation, SOR (alcohol, polymers, surfactants injection)
Thermal: steam injection (to heating of the reservoir to lower the viscosity)
Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fiel...Juan Diego Suarez Fromm
Two field examples will be presented, where after 50 years of development; fresh oil and gas were produced by changing some reservoir paradigms.
Upsides could be overlooked due to paradigms on field development. The successful one in terms of reserves and cost effective capital expenditure could be visualized as “finding the key for the field”. But as development takes place over many years (decades), the “key” should be a dynamic concept over time, correlated with technology availability, enabling us a better understanding of petroleum resources size, quality and distribution.
Water Balance Study is carried out for a Super Thermal Power plant as a part of the M. Tech final
project which is published in the Sustainable Water Resources Management (Springer) Journal (https://
doi.org/10.1007/s40899-020-00487-4).
To determine the optimum pipe diameter, you should go make the comparative analysis to determine the most optimum pipe size which reflects the most economic option.
This example is for illustration the importance of the the comparative analysis.
Note: According to ASME, pipe with 5 in diameter is not standard, but i selected it in the example for illustration only.
Mark Killar, Western Pennsylvania Conservancy, “Sewickley Creek Cost/Benefit ...Michael Hewitt, GISP
Throughout Pennsylvania, many non-profit organizations have developed restoration plans for AMD impaired watersheds. To secure federal AML funding through Pennsylvania’s Abandoned Mine Reclamation Program and with other federal programs, those plans must include a cost/benefits analysis to assure that funds from the program are spent wisely. In an effort to assist in the development of a cost/benefit analysis for AMD projects being proposed for a qualified hydrologic unit watershed, Western Pennsylvania Conservancy worked with Hedin Environmental, through a technical assistance grant provided by Trout Unlimited’s Eastern Abandoned Mines Program, to develop a treatment cost calculator, which could compare costs on a variety of AMD treatment types. This presentation will demonstrate how it was used to develop a cost/benefit analysis for priority AMD discharges within the Sewickley Creek watershed in Westmoreland County.
Improving Energy Efficiency of Pumps and Fanseecfncci
Pumps and Fans are energy consuming equipment that can be found in almost all Industries. Therefore, it is important to check if they are running efficiently. This presentation give an overview about energy saving opportunities in pump and fan equipment. It was prepared in the context of energy auditor training in Nepal in the context of GIZ/NEEP programme. For further information go to EEC webpage: http://eec-fncci.org/
Cartridge Valves for Submarine, Aircraft Carrier Rocket Launcher – CunicoCunicoCorp
Cunico manufactures high quality Cartridge Valves for Submarine, Aircraft and Carrier Rocket Launcher. Valve Cartridges are Interchangeable within each Valve Body.
Cunico manufactures high quality Cartridge Valves for Submarine, Aircraft and Carrier Rocket Launcher. Valve Cartridges are Interchangeable within each Valve Body.
Water utility budgeting flood to drought-understanding and predicting variabl...
Bachman_SPE_TightOil_2015-04-29_ForRelease
1. Evaluating Completion Effectiveness
of Horizontal Multi-Staged Fractured Wells
in the Pembina Cardium Field
SPE Tight Oil Workshop
2015-04-29
by Bob Bachman (RBachman@TaurusRS.com)
1
A CGG Company
3. Question
• What metrics are you using to assess your
horizontal wells ?
– Depends on objectives
• Completion Effectiveness
• Ultimate Recovery or Reserves
3
4. Review of Flow Regimes
• SRV Linear Flow
• Compound Linear Flow
• Bounded Flow
4
5. Well is black line
Fractures are solid
gray lines
No flow
boundaries are
dashed gray lines
Flow can only
occur into the well
through the
fractures
SRV Linear Flow
1. Length = Sum of all fracture lengths
which normally can be estimated
Production metric should
be normalized with respect
to number of stages
5
6. Well is black line
Fractures are solid
gray lines
No flow
boundaries are
dashed gray lines
Flow can only
occur into the well
through the
fractures
Compound Linear Flow
2. Length = Distance between toe and heel
fracture treatment
Production metric should
be normalized with respect
to stage spacing
6
7. Completion Effectiveness Requirements
• Want to be in SRV Linear Flow
– Want flow regime to last ~ 1 year
• Need low permeability
– Public monthly data being used
• Cannot be affected by waterflooding
• Can be rate or cumulative
– Candidates
• Maximum oil/fluid rate over 6-7 months
• Cumulative oil/fluid after 1 year
7
8. Pembina Cardium
• Canada’s biggest oilfield
• Discovered in early 1950’
• Waterflood started in late 1950’s
– Light oil
– Heterogeneous with low recovery
• Renewed interest in fringe or ‘halo’ low
permeability areas in early 2000’s
• Multi-stage horizontal fracturing begins
2006
8
9. Pembina Cardium
• Well candidate requirements
– Horizontal wells in sections with no injection wells
• 501 wells
– Review watercut in wells
• Clean-up behavior
• Influence of off-section injection
9
11. Early wells from 2006 through 2009
-½
-1/1
End linear flow tmbo = 800
days or 400 actual days
Late time data being affected
by offsetting waterflood
patterns
First Order Material Balance Time = Cum/q
11
12. Early wells from 2006 through 2009
-½
-1/1
End transient flow tmbl = 1000
days or 500 actual days (one
exception)
Late time data being affected
by offsetting waterflood
patterns
12
First Order Material Balance Time = Cum/q
14. Wells from 2014
from one township
still in linear flow tmbo = 600
days or 300 actual days
-½
-1/1
14
First Order Material Balance Time = Cum/q
15. Wells from 2014
from one township
-½
-1/1
still in linear flow tmbo = 600
days or 300 actual days
Late time data not affected by
any water injection 15
First Order Material Balance Time = Cum/q
16. Wells from 2014
from one township
Water production drops
due to clean-up
Cleanup of completion
fluid 16
17. Final Production Metric Selection
• Cum Oil at 365 days (12 months)
• Normalize on number of stages
17
24. Foamed Water - Median Properties
Well Count = 8
Well Length = 1230 m
Stages = 14.5
Prop/Stage=21.7 Tonnes
Eff Fluid/Stage = m3/Stage
Conc = 173 kg/m3
Comp Cost/Stage = 56.3 k$
12 Month Cum Oil/Stage =309.0 m3
Comp Cost/ 12 Month Cum Oil =29.00 $/stb
24
Eff Fluid = Effective Fluid
accounts for gas volume for foam based fluids
at downhole conditions
When there is no foam, equals base fluid
28. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
OilWat 462.1 25.6
28
Eff Fluid = Effective Fluid
accounts for gas volume for foam based fluids at downhole
conditions. When there is no foam it is same as base fluid
Not many OilWat data samples, a manual review of these
entries showed no clustering of wells within one area.
29. 29
Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
E_SlickW 253.0 35.9
30. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
Water 254.5 45.3
30
31. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
Water 254.5 45.3
E_Water 222.7 54.3
F_Water 309.0 29.0
31
32. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
Oil 195.3 90.7
32
33. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
Oil 195.3 90.7
E_Oil 189.8 91.9
33
34. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
F_Surf 194.5 49.8
34
35. Entries in Table are Median Values
12 Month 12 Month
Fluid Cum Oil/Stage Comp Cost/Cum Oil
m3/Stage $/stb
SlickW 215.6 44.4
F_Water 309.0 29.0
OilWat 462.1 25.6
Final Comparison Plot
35
36. Final Conclusions
• Slickwater is not the optimal fluid for stimulating
the Pembina Cardium
• Polyemulsions were the best
– Were commonly used in the Pembina Cardium for
decades
– Not much current use
• Foams are the second best fluid system
– readily available
36
40. Appendix 2
• Does proppant concentration matter ?
– Need to use example from Montney gas region
recently studied
– Conventional wisdom is that gas needs longer fracture
lengths not more conductivity
• Therefore high proppant concentrations may not be
necessary
– Is this true ?
40
41. Montney Heritage Area
Comparing Slickwater to CO2 Foam
CO2 foam gives superior fracture properties with less
fluid as compared to slickwater
For CO2 foam, more fluid per stage (lower overall
proppant concentration) has negative effect
CO2 foam gives superior fracture properties with
less proppant as compared to slickwater
For CO2 foam, more proppant per stage at high
proppant concentration has positive effect
41