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Microseismic Mapping Services

Mapping Your Hydraulic Fractures – in Real Time

November, 2013

Dick Zinno, Chief Geophysicist


Microseismic Hydraulic Fracture Stimulation Diagnostics

• What is (Passive) MicroSeismic Monitoring?

– Using Stimulation-Induced Microseismicity (“Tiny Earthquakes”) to map fracturing?

– Injection (fracturing ) in situ stress changes microseismicity

• How is microseismicity recorded?

– Wireline-deployed motion-sensor (“sonde”) array in borehole records shaking (“wiggles”) from induced microseismicity (“events”)

• What information is in the “wiggles”?

– “Microseismic” – length, height, width & azimuth of fractured zone, event occurrence sequence, event size, and rock failure mechanism

• Is it a Proven Technology?

– YES!

– Injecting Induces Microseismicity! e.g., mining, geothermal, gas storage, liquid & slurry waste injection industries


Why Microseismic Monitoring?: Hydraulic Fracture Geometry, Drainage Patterns, Field Optimization

What Do You Create when You

Hydraulic Fracture?

Lots of

Possibilities!!

13ADU9 - SPE WORKSHOP: Addressing the Petrophysical Challenges Relevant to Middle East Reservoirs 3


Factors Affecting Induced Seismicity Amplitude

“Brune” Earthquake Model

1. Radius of Slip

a. Circular Fracture: Radius “r”

b. (Pre-existing Natural Fracture)

2. Friction on the Slip Surface

a. Rock Strength: Young’s Modulus

b. Roughness of Fracture Surface

c. Confining Stress

d. (Fluid in the Fracture)

3. Displacement of Slip (Strain): “d”

a. Amount of Stress Released

b. (Volume of Fluid Injected)

c. Resistance to Deformation

a. Poisson’s Ratio

4. Velocity of Slip: “v”

1. Rate of Stress Release

2. (Rate of Fluid Injection)

3. (Permeability of Formation)

4. (Viscosity of Injected Fluid)

5. Seismic Wave Attenuation

a) Distance to Geophone

b) “Q” of Formation: Young’s Modulus

6. Ambient Noise

1. Surface Activity

2. Reservoir Activity

1. Drilling, Pumping, Production

4


“Brittleness” Increases Recordable Microseismicity

Eastern

Middle

Western

Young’s Modulus

Poisson’s Ratio High “Brittleness”

Low “Brittleness” = “Ductile”

13ADU9 - SPE WORKSHOP: Addressing the Petrophysical Challenges Relevant to Middle East Reservoirs 5


Treatment well Monitor Well

Grid spacing = 100 m

(sidetrack)

Big Natural Fracture into the Lower Limestone

Region of Complex Fracturing in the Target Shale Interval

Very Hard Rock (High Young’s Modulus – Low Poisson’s Ratio) Will Generate Many Very Strong Seismic Signals

Example from China, 2012 – 6,722 events (1 Well)

6

Map View


Grid spacing = 100 m Big Natural Fracture into the Lower Limestone

Region of Complex Fracturing in the Target Shale Interval

Not Knowing That Many Of Your Stages Are Fracturing Into A Fault – Case For Real Time Monitoring

7

Break into Limestone

With Drop in Pump Pressure and Large Magnitude Emissions

7


Enough Information for a “Head to Head” Comparison of Completion Methods

Events located by combined

horizontal and vertical arrays.

One Jetted Port per Stage

Plug and Perforate

Zone Select

Map View

Very Soft Rock (i.e. High Clay Content Clastics) Will Generate Fewer and Weaker Seismic Signals

Example from Canada , 2009 – 481 events (3 wells)

8

8


The Most Important Factor in Reservoir Development Are Natural Fracture Systems Influencing Drainage

Conjugate Joint Sets

Small Faults and Fractures

Large Faults

9


Failures Along Tectonic Faults

Appalachian Road Cut


Reservoir Management

Unconventional Reservoir: Stimulation Affected by Large Tectonic Fault – Unexpected Fracture Porosity! Enhanced Drainage! Excellent Producer!

-Surprises !!

Marcellus

perforations

Range Resources, 2006


Fractured Reservoir Model Geomechanical model with Discrete Fracture Network Will Accurately Predict Fracturing Behavior (further requirements stated in Conclusions)

Plan view of hydraulically stimulated

joint network in granitic rock from FRIP, out of

[Pine and Batchelor, 1984]

Devonian Shale Outcrop

- Allegheny Plateau

12


Unlocking the Secrets of Barnett Shale Gas Development Mitchell Energy – March, 2000

Microseismic diagnostics reveal irregular drainage pattern

due to natural fractures (a fact held secret for several years)


Elongate Fracture Patterns Mitchell Energy – March, 2000 – Barnett Shale

The Justification for Horizontal Drilling in Shale

A B


Overlapping Fracture Growth: Multiple Horizontal Wells – Basis for Simul-Fracs

EOG Resources – September, 2005

This fracture is stimulated multiple times during multiple stages

15


Overlapping Fracture Growth: Re-stimulating The Same Fracture

Causes Fracture Break-outs into Deeper Zones

16


Overlapping Fracture Growth Failing to Optimize Pre-existing Structures: Horizontal Wells Drilled In-Line with Azimuth of Favored Joint Set

microseismic events scaled by sub-sea depth

(useful during Real Time Monitoring – to avoid deeper water bearing zones)

Geophone Array

17


Wide Fracture Growth Optimizes Pre-existing Structures: Horizontal Wells Perpendicular with Azimuth of Favored Joint Set Range Resources, 2009

microseismic events scaled by individual stimulation stage

(useful during Real Time Monitoring – to select subsequent perforation intervals)

18


Failures Along Conjugate Joint Sets (Jointing passes through lithologic horizons)

Devonian (Marcellus Shale) Outcrop, Allegheny Plateau


Horizontal Well – with downward growth Frac has a total lack of lithologic confinement

Range Resources, August, 2007 Fortunately, for this portion of the reservoir, surrounding zones are DRY

Marcellus


Horizontal Well - Avoids Salt Water Zone successfully limited downward frac growth

Atlas Energy, March, 2009

Early stages frac into a large fault – luckily does not grow downward

Salt Water Zone

Oriskany Sandstone


CMI Logs from West Siberia Basin

CMI Fracture Azimuths are Consistent

with Microseismic Fracture Patterns,

Interpreted as Conjugate Joint Sets

Conjugate Joint Sets are Similar

Across Entire Basins

22


Improving Recovery

23

• Microseismic mapping reveals the actual stimulation pattern (unanticipated complications).

• Improved completions by changing well trajectory, to avoid East-West natural fractures.

• All fractures from all stages are now well contained within their target zones.

• Total stimulated rock volume is increased (longer frac lengths), for 300% improved recovery.

• Stimulation procedures can be modeled and improved with a full geomechanical analysis; using full suite of electric logs, image log, discrete fracture network, lithology section, in-situ stresses, reservoir pressures, past stimulations data, plus designed pump pressures, injection rates, and injection volumes. (Core analysis values are optional.)

Early Wells Redesigned Well


Offset Well MicroSeismic Services


Wireline Operations

• Setup

– Remote Well ≤ 2,000 ft from treatment well

• Remote Well Operations

– Self-Contained Field Unit

– Deploy 8-level, 3-component geophone array on standard, 7-C wireline in the well

– Record Microseismicity continuously before, during, and after HF Stimulation

– Process and Map microseismicity in real time or process and map offsite, after stimulation

– Stream seis-map to frac unit for on-site display


Wireline Multi-Level Seismic Arrays

• Designed specifically for recording high-frequency, signals, this tool is at the

forefront of available seismic equipment. Superlative performance for high

resolution VSP and Microseismic monitoring.

• 1 11/16” diameter, 44” long, weight

14 lbs

• Combinable with Gamma ray and

Casing Collar Locator tools on 1-C,

3-C or 7-C wirelines

• 0.25ms to 4ms sample rates

• 24-bit delta sigma convertors

• >122 dB Dynamic range

• Lowest noise floor in the industry

• Digital tool array with up to 24

satellites

• 3-component geophone cartridges

with fixed 15Hz or 30 Hz sensor

elements

• 150C maximum temperature rating

• 14,000psi pressure rating

• Electrically operated clamp arm

range from 2” to 13” with optional

caliper arms


Treatment Well MicroSeismic Services


Two Microseismic Frac Monitoring Options

Treatment Well Observation Well

1. Treatment Well Array 2. Observation Well Array

Real Time

Drainage Volume

Height/Containment

Azimuth/Length/Continuity/networks


The “Spear” Array

• Setup

– Deployment during treatment : at depth or in lubricator

• Treatment Well Operations

– Deploy 3-level, 3-component, rigid array with telemetried press., temp., and gyro in the treatment well !!

– Record microseismicity during pre-treatment pad and post-treatment shut-in stages

– Process and Map microseismicity in real time or process and map offsite, after stimulation (recommended)

– Stream seis-map and downhole pressure to frac unit for on-site display


“Spear” Setup and Deployment - Summary

Insert in lubricator on surface

Hoist lubricator on to stack Tool ready for deployment

Lower tool slowly during pumping or park in Lubricator – record when pumps are off

Bring back in to lubricator for safe retrieval


E-Coil (push & pull)

Microseismic Spear Deployed on eCoil

• Occasionally, wellhead pressure is too great

to let the tool drop from the lubricator, so we

have developed a new method, using e-coil,

whereby we push the tool into the well

• This will open up the possibility of pushing

the tool horizontally if required

• Benefits of this include an increased

breaking strain for the head and an ability to

circulate fluid around the top of the tool

should it become sanded in.

Treatment Well


Geophones

Treatment

Well

Perforations

No Observation Well

Required !!

Treatment Well Microseismic Operations

Fracture

Extent

~400 m

Actual

Case History

Data

“Penny Shaped”

Fracture

In Treatment Well Microseismics


In Treatment Well Microseismics Petroedge Resources, October, 2009

~50 m

Pilot Well Microseismic diagnostics indicate successful containment above water zone


Microseismic Spear: Results in Coal Bed Methane - Indonesia

Well bore

N330°W

Fracture Analysis:

Stimulated Rock Volume (SRV); Fracture Azimuth, Zone Containment,

And Fracture Complexity Index

(FCI)

Well Bore

Coal 3

Coal 2

Coal 4

Coal 1

34 13ADU9 - SPE WORKSHOP: Addressing the Petrophysical Challenges Relevant to Middle East Reservoirs


Permanent Array MicroSeismic Services


Permanent Array Deployment in Production & Injection Wells

36

Ruggedized

Sensor Carrier

3-C Sensor

Array Spooling Unit Sensor

Mandrel

Clarion Fiber Optic Array: Tubing or Casing Conveyed



Continuous Passive Monitoring For Producing Fields

37

Pressure, Temperature and Seismic Monitoring

16000 m0

0 8000m

CO2 Injection Well, South France

Deep Monitor Well, Kazakhstan



Surface Array MicroSeismic Services


Surface Microseismic for Hydraulic Fracture Monitoring

39

Lower resolution

due to depth below

geophone array


Surface Microseismic for Natural Fracture Reconnaissance Can Be Acquired with 3D Reflection Survey

40

Lower resolution

but wide detection area


ActiveModel Complete MicroSeismic Data Integration


Geomechanical Modeling: Fully Interactive, Integrated Data Sets,

Real Time, Multiple Users, Multiple Locations

• Vector Plots

• Curvature

• Fracture Import

•Discrete Fractures Are Opened in a

Real Time Modeling Package

42


Full Data Integration: Fracture Analysis (using all available measurements)

Surface Locations

Treatment Well

Stage 1

Stage 12

Stage 6

Stage 5

Stage 4

Stage 1 Stage 2 Stage 3

Stage 7 Stage 8 Stage 9 Stage 10 Stage 11 Stage 12

Compass

Treatment well Logs could be:

MWD GR Log

Density of Open Fractures

Density of Partially Open Fractures

Density of Healed Fractures

Map View of a Project Well, in ActiveModel, with Interpreted Well Log Data


Length Perpendicular to Wellbore

Length 50° Azimuth

Stage 5 to 7

Stage 1 to 4

Microseismic Fracture Analysis: Azimuth, Stimulated Rock Volume, Correlation to Image Log

120°

117°

120°

125°

120°

115°

60°

60° 60

°

55°

55°

Interpretation Includes

Drilling and Completion

Recommendations

Stimulated Rock Volume (SRV)

Fracture Complexity Index (FCI)

Correlation of Fractures to Image Log


Conclusions

• Microseismic Monitoring is a Widely Accepted Method

• Microseismic Maps Are a Key Data Set for Reservoir Development

• Accuracy and Completeness of Microseismic Maps Depends on:

– Proximity of Geophones to the Reservoir

– Rock Properties

– In-Situ Stress

– Controlling Other Acoustic Noise Sources

• Geologic Structures’ Influence on Drainage Patterns Can Be Understood

• Microseismic Mapping is Key to the Integration of Multiple Data Types

• Borehole Monitoring Methods offer the Most Accurate Maps

• Surface Microseismic Monitoring Can Be Useful In Certain Conditions

• Full Geomechanical Modeling in Real Time Is The Future for Reservoir

Development


References

• Gale, Julia F. W. (2007) Natural fractures in shale gas plays – why they are important,

Poster Session, AAPG, Annual Meeting, Long Beach, CA

• Pine, R. J. and Batchelor, A. S., (1984) Downward migration of shearing in jointed rock

during hydraulic injections, Int. J. Rock Mech. Min. Sci. & Geomech. Abstr. 21,5, pp.

249-263.

• Urbancic, T., Maxwell, S., Steinsberger, N., Zinno, R, (2003), SPE 77440,

Microseismic Imaging of Hydraulic Fracture Complexity in a Naturally Fractured

Reservoir, SPE Annual Meeting

• Zinno, R., Gibson, J., Walker, R., Withers, R., (1998), Overview: Cotton Valley

Hydraulic Fracture Imaging Project, SEG 68th International Annual Exposition and

Annual Meeting, New Orleans, LA

• Zinno, R., Gibson, J., Walker, R., Withers, R., (1998), Overview: Cotton Valley

Hydraulic Fracture Imaging Project, SEG 68th International Annual Exposition and

Annual Meeting, New Orleans, LA

• Zinno, R., Rubtsova, A., Bezouchko, L., Naumov, Y., (2013), First Successful

Microseismic Campaign in Russia, Results and General Criteria for Successful

Application, Lessons Learned and the Way Forward, EAGE/SPE Joint Workshop:

Geoscience Monitoring of the Field Development Process, Moscow, Russia


Thank You!

Questions & Answers

47

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