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Eagle Ford Shale Stimulation Demands: Good Engineering, Optimized Fluid Selection and Execution
Jorge Manrique, PE – Nabors Completion & Production Services Co. Buenos Aires, 9 de Agosto de 2012
Who we are…
5th Largest Pressure Pumping Co. in North America (~1 M HHP)
Experienced in All Major US Basins (29 Districts)
Over 13,600 DUG Stages Completed in 2011
HRHP Equipment and Experienced Personnel (15K PSI)
World Oil, Eng. Innovation Awards & Patented Green Chemicals
Pioneers in Water Re-use
Friction Loop Analysis
Own RC Proppant Technology Available
In-House Engineering / Design Optimization
• Pressure Pumping Cementing Fracturing
• Wire Line• Coiled Tubing (16)• Work Over Well Servicing (750)• Fluid Management, Storage & Disposal• Transportation & Logistics
What we do…
Washington
Oregon
California
Nevada
Idaho
Montana
Wyoming
ColoradoUtah
New MexicoArizona
Kansas
Nebraska
South Dakota
Minnesota
Wisconsin
Illinois
Iowa
Missouri
Arkansas
Alabama
Tennessee
MichiganNew York
Vermont
Florida
Mississipp
i
Kentucky
South Carolina
North Carolina
MarylandOhioDelaware
N. Dakota
Pennsylvania
Oklahoma
Indiana West Virginia
New Jersey
Connecticut
Massachusetts
Maine
Rhode Island
Virginia
New Hampshire
Haynesville & Bossier Shale Play
Dallas
Barnett Shale Play
Cotton Valley Gas Play
Deep Bossier Gas Play
Tyler
Texas
Bone Spring Play
Avalon Play
MidlandOdessa
Wolfberry Play
Shreveport
Houston
Eagle Ford Shale
Lafayette
Tuscaloosa Marine Shale Play
EAGLE FORD
TUSCALOOSA MARINE
HAYNESVILLE
WOLFBERRY
BONE SPRING
AVALON
Pleasanton
Wilcox / Lobo Trends
BAKKEN
FAYETTEVILLE
San Jaoquin Basin(medium – shallow drilling)
Los Angeles
San Francisco
N. California Gas Play
Geothermal
WAMSUTTER
PINEDALE
PICEANCEUNITA
NIOBRARA
Casper
Cheyenne
Denver
Williston
Bismarck
Bakken Play
Sanish Three Forks
MARCELLUS
UTICA
Utica Shale (below Marcellus)
Marcellus Shale
OKCCANA
WOODFORD
WOODFORDGRANITE WASH
MISSISSIPPIAN
LIME
Major US Unconventional Basins
NCPS Districts
250 Rigs Un-conventional
VACA MUERTA EAGLE FORDMARCELLUSHORN RIVER BARNETT HAYNESVILLE
2352 FT 600 FT 498 FT 351 FT 298 FT 219 FT
Comparison of Shale Thickness
Vaca Muerta is ~7 times Thicker than Eagle Ford Play
OIL
DRY GAS
EAGLE FORD SHALE BASIN
• X-Ray Diffraction (XRD)• Total Organic Content (TOC)• Pressure/Volume/Temperature (PVT)• Embedment• Geo-Mechanical
If <YM = SoftIf >YM = Brittle
• Desorption Analysis
Understanding the Shale Reservoir
Total Improved Production and EUR depend on:
• Complex Fracture Geometry
• Optimal Perforation Techniques
• Stress Contrasts
• Fluid Leak-Off
• Natural Fractures
• Layering
• Brittleness
• Young Modulus
The Importance of Understanding the Reservoir
Laboratory Services & Testing
Sample Depth (ft) Lithology Classification
No. (modified Dunham, 1962)
1 10170.50 Calcareous Mudrock N/A2 10174.40 Calcareous Mudrock N/A3 10183.70 Calcareous Mudrock N/A4 10189.50 Argillaceous Limestone Foraminiferal Packstone
5 10192.40 Calcareous Mudrock N/A6 10195.50 Calcareous Mudrock N/A7 10201.50 Argillaceous Limestone Foraminiferal Packstone
8 10213.55 Calcareous Mudrock N/A9 10219.50 Mudrock N/A10 10221.80 Claystone / Calcareous Mudrock N/A
11 10225.50 Mudrock / Calcareous Mudrock N/A
12 10241.50 Mudrock / Calcareous Mudrock N/A
Samples Examined
Courtesy of Southern Bay Energy
Frac Fluid Design Based on:
• Inductive Coupled Plasma (ICP)
• PMAC Scale Modeling System
• Microbiological Analysis
• Standard Titrations
• Field Tests
• Post Job Analysis of Produced Water
• 5 Clusters
• Reduced Spacing to 1 Ft
• 4 SPF (all deep penetrating)
• Run RA Tracers (Ir, Sc, Sb)
• Drilled-Out Frac Plugs & Log the Interval
Perforating and Fracture Initiation
20 Holes – Limited Entry
25# Crosslinked Hybrid – Eagle Ford
Conclusions
• Formation Evaluation & Core Data correlation will enhance best frac design.
• Each shale formation is unique in geo-chemistry, petrology, brittleness, ductility, complexity, mineralogy. All must be understood to select the right fluid rheology.
• There is no a single approach to complete all shale formations.
• Mineral deposits and geochemical precipitates including scale, can be prevented by using the right blend of chemicals.
• Limited-entry and deep-penetrating shots have proven effective at reducing fracture initiation pressures, lower breakdown pressures and “smoother” treatment.
• Maximizing the Stimulated Rock Volume (SRV) can be obtained through limited- entry perforating designs.
• Smaller diameter holes create additional friction pressure aiding in fracture diversion.
• Frac treatment must be designed depending if the well will produce oil or gas.