Fractured Injection Design and Monitoring - gwpc.org REVISED_0.pdf · Fractured Injection Design and Monitoring Omar Abou-Sayed ... Mixing Tank 4. Electric Pumps 5. ... storage volume,

Fractured Injection Design and Monitoring

Omar Abou-Sayed

CEO, Advantek Waste Management Services

832.265.0511 | [email protected]

www.advantekwms.com

Copyright 2018 Advantek Waste Management Services LLC. This material is private and confidential 2

Fractured Injection: A Primer

Fractured injection is standard practice• Fractured injection is a standard practice for

managing solid wastes in environmentally

sensitive regions including offshore, tundra,

marsh, and remote areas

• Injected waste would otherwise be discharged

to ocean, left in reserve pits, or land-farmed

• Injection of slurry relies on hydraulic fracturing

science to create subsurface voids in which

solids are stored

Best practices are critical to success• Proper feasibility studies, well construction, and

zonal selection are all critical to achievement of

waste disposal objectives

Safe operations require real-time monitoring• Best practice uses well surveillance and control

to continually monitor both surface pressure

and subsurface fracture behavior to assure

containment at all times


Injection can solve many current acute waste issues


Historical and Current Applications

Nuclear Waste (1960’s-1987)

• Frist applied at Oak Ridge National Laboratory from the 1960’s – 1987, low level

radioactive water was used to make a cement which would set in the subsurface,

binding the radioactive isotopes in place

Oil and Gas Wastes (1987-Present)

• First large scale project was in Alaska North Slope. Widespread adoption in

offshore followed along with some major onshore facilites

BioSolids (~2009-Present)

• Recent Class V project in Los Angeles (biosolids)

• Obviates land-farming + long distance hauls and sequesters CO2 and CH4

Other Applicable Wastes

• Technique can solve many other urgent waste issues (NORM, organics, mining

and power, superfund, gypsum stacks, petrochem, barge / bilge / dredge…)

From a 1998 EPA report: “The deep injection of waste [enabled by slurry injection] is the

only disposal option that effectively removes waste from the biosphere.”


Biosoilds Injection Demonstration Deep Well Injection Facility – T.I.R.E.

The Terminal Island Renewable Energy

(“TIRE”) project is the USA’s first full

scale facility to dispose biosolids, brine

effluent and tertiary effluent by deep

well injection and geothermal

biodegradation

• Initiated operations in July 2008 as an

EPA demonstration project

• New EPA permit approved December

2013 (allowing construction of 4th well,

deepening of wells to 7,500 feet,

alternating injection into two wells, and

construction of replacement wells as

needed)

• Site now manages 100% of the biosolids

from the City of Los Angeles Terminal

Island Plant and about 20% of the

residuals output from the Hyperion

Treatment Plant


We are sequestering large amounts of greenhouse gas and reducing risk

Deep well sequestration eliminates environmental impacts from landfarming,

reduces operational risks, and provides significant GHG emission reductions

11

22

33 44

66 55

77

Advantek’s TIRE facility in LA1. Biosoilds blending pit

2. Screen system

3. Mixing Tank

4. Electric Pumps

5. Injection Well

6. Monitoring Well

7. Office

12 mos at current rates (projection)

% of City Biosolids Diverted 20-25%

Biosolids Injected (gals) 80 million

GHGs avoided

or sequestered

8,072 tons CO2 + 5,090 tons CH4 + 0.05 tons Nox

=~115000 MT CO2e per year

Road miles eliminated 395,200 miles

Injuries and Fatalities avoided 1 every 7.6 years


Technology Overview: Slurry vs Water Injection

Salt Water Disposal Wells:

• Typically inject water directly into the

disposal zone’s rock matrix

• Total capacity is determined by the

volume of the disposal reservoir

• Disposal zones are selected based on

isolation from freshwater sources

Fractured Injection Wells:

• Inject solids by grinding them with

water to create slurry and injecting

the slurry into naturally occurring

hydraulic fractures or those created

during the injection process

• Capacity determined by the volume of

the fractures accessed during injection

• Disposal zones are selected based on

isolation from freshwater sources and

stress barriers which prevent fracture

propagation beyond the permit zone

Fresh water aquifer

Permitted disposal zone (e.g., Brine Aquifer)

Fracture

SWD Well

Solids

Injection Well

Impermeable rock layer arrests migration of injected salt water

High stress layer restricts fracture propagation in solids injection

Water is injected into porous reservoirs while

solids are injected into created hydraulic fractures


Achieving best practice requires attention to three key activities

Feasibility, site selection,

and permitting

Establishing that a target

zone provides a safe

operating window

considering geological,

geomechanical, and

seismicity data requires

sophisticated analysis.

Ongoing, real-time

operational monitoring

Monitoring is crucial for the

long term assurance of

waste containment and well

integrity, as well as the safe

maximization of disposed

volumes.

Well logging, testing and

process design review

Initial analysis using offset

well data must be reviewed

once the well has been

drilled to target and the true

formation properties tested.

Successful operations must focus on all three areas


Massive parametric study

informs well design and

operational protocols

Establishing feasibility & designing a well requires sophisticated analysis

Feasibility and safe well capacity are determined using a workflow based on well

logs, offset well performance, geomechanics and fracture simulation & optimization

Well data storage /

access

Log based geomechanics

Fracture simulation

and optimization

Half Fracture Length (ft)

Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081

Fracture Shape and Width (inches)(V = 14000 bbls at 4 bpm w/o Solids)


Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081



Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081



Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081



Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081



Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081



Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081



Fra

ctu

reH

eig

ht

(ft)

0 500 1000

-400

-300

-200

-100

0

100

200

300

400

500

1.106

1.0330.959

0.8860.813

0.740

0.6670.594

0.5200.447

0.3740.301

0.2280.155

0.081


Fea

sibility, S

ite S

ele

ction

, an

d P

erm

itting


Simulations using real field data allow strong assurance of containment

Fracture behaviors are predicted by geomechanical

modeling and verified using periodic well tests

Safe margins are built into operating procedures

• Log analyses + breakdown and fall-off tests determine

properties of both the injection zone and overlying

formations (cap rocks and intermediate zones)

• Fracture and flow simulations are used to predict and

confirm containment within the injection zone

Identifying barrier zone and mechanism is critical

• Stress: Fracture energy insufficent to crack zone

• Stiffness: Fracs become very narrow causing high

friction losses and plugging which arrest propagation

• Permeability: High perm syphons off fluid energy

Fea

sibility, S

ite S

ele

ction

, an

d P

erm

itting


Best Practices in Well Construction for Cyclic + Abrasive Injection

Element Practice

Well head Typically inspected bi annually for erosion and corrosion, and is replaced as needed

Tubing

Coated tubing aids in minimizing erosion and corrosion issues due to the abrasive

nature of the slurry. The annulus pressure will be monitored to detect any pressure

communication between the annulus and the tubing which would signify a possible

need to change tubing

Packer

Packer settings (tension, compression, neutral) are chosen carefully such that the

net force is always from one side whether during injection, fall off, or resting. This

aids in minimizing the risk of a packer being unseated due to cyclic forces

Cement

Cement is set through the containment layer (Queenston, Reedsville, Utica, and

Pleasant shales) to prevent fluid migration out of zone behind the casing. A cement

bond long is studied to assure the quality of the cement before injection

Particle SizeThe maximum particle size of the solids in the injected slurry is controlled (usually

below 300 microns) to minimize the tubing erosions and solid settlings issues

Flushing

After each batch injection, the wellbore and surface piping are flushed with clear

fluid to prevent settling of solids in the wellbore which could cover the

perforations. Larger flushing events are done periodically to help sweep solids

away from the near wellbore to help minimize injection pressure rise

Geometry Eliminate / reduce use of 90 degree turns to reduce the erosion wear issues

Fea

sibility, S

ite S

ele

ction

, an

d P

erm

itting


Once the well is drilled, initial design parameters must be remodeled

1. Feasibility

assessment and

option

identification

2. Preliminary

design

3. HazId/HazOp

and permit

support

4. Injection test

and process re-

design

We

ll Log

gin

g, Te

sting

, an

d P

roce

ss De

sign

Re

vie

w


Ongoing, real-time operational monitoring requires close collaboration

Field operators and subsurface engineers must work together to

monitor and control the well

• Well performance

• Well-head pressure

• Injection rate

• Operational procedures

• Correct batch times and rates

• Correct flushing volume

• Slurry rheology

• Correct slurry viscosity & density

• Correct particle sizes

Safe operations must be the highest priority• Both surface and subsurface risks must be constantly evaluated using real-

time surveillance to ensure that surface pressures and subsurface behaviors

are within bounds

On

go

ing

, Re

al-tim

e O

pe

ratio

na

l Mo

nito

ring


Fracture closure and propagation

pressures are interpreted through the

step rate test to confirm fracture

geometry and injection zone

MARATHON KU12-17 FOT

10-4 10-3 10-2 10-1 100 101 102 103 104 105

10

-710

-610

-510

-410

-310

-210

-1

Delta-T (hr)

DP

& D

ER

IVA

TIV

E (

PS

I/S

TB

/D)

2011/11/29-2047 : OIL


0. 10. 20. 30. 40. 50.

-7000.

-4000.

-1000.

Time (hours)

ST

B/D


0. 10. 20. 30. 40. 50.

1000.

1500.

2000.

2500.

PS

I

* : OIL

SELECTION OF PRESSURES DATA (PSI)

Gauge-Data ID: GAU001

Analysis-Data ID: GAU001

Total Raw points = 185464

Set 2 rates (max=100000)

Loaded 3 points (max=100000)

Pressure Select Mode: AUTOMATIC

Rates Cum. Prod.= -1306.0906 BBLS

Static-Data and Constants

Injection fall off data can be analyzed for

information on fracture containment in-

zone, near-well damage, and reservoir

properties

Correctly gathered data provide deep insights into subsurface dynamics

Step Rate TestFall-Off Test

Too often, operators of injection (including water) facilities gather data only to the

extent minimum required by regulation, rendering proper analysis and diagnostics

impossible. Real-time monitoring and data archiving should be mandatory.

On

go

ing

, Re

al-tim

e O

pe

ratio

na

l Mo

nito

ring


Fall-off data can be used to provide deep understanding of the fracture behavior

Standard fall off test analyses:

• Formation properties such

as: permeability, reservoir

model, near wellbore skin

• Fracture properties such as:

Geometry (L, W, H),

conductivity, skin, closure

pressure

• Trends in closure pressure

can forecast zonal capacity

On

go

ing

, Re

al-tim

e O

pe

ratio

na

l Mo

nito

ring

Advanced fall off test analyses:

• Fracture properties: out of zone propagation, cross

flow, interference with another well / fault, fracture

shrinkage during closure, extent of inner / outer

domain (plume), storage volume, stress contrast with

confining layer


Temperature logs can also identify fracture height / containment

Temperature gradient logs can correlate

fluid plume / fracture height to rock

temperature changes induced by the

injected fluid

Can also illuminate flow behind casing or

tubing, such as channeling

Can identify casing, tubing, or packer

leaksTop of the injection

horizon. No water

migration above this

depth.

Injection horizon has lower

temperature than the

overlying formation since

injecting fluids tends to cool

down the formation

On

go

ing

, Re

al-tim

e O

pe

ratio

na

l Mo

nito

ring


USGS data enables ongoing seismic monitoring to underpin “traffic light” systems

Seismicity monitoring can be enabled

using USGS systems, private monitors,

or both

In-well seismic monitors can

complement the data, but are

mechanically unreliable

Careful thought must go into the

method of monitoring to minimize well

interventions while providing data

needed to enable “traffic light”

programs which curtail injection wells

near established epicenters

On

go

ing

, Re

al-tim

e O

pe

ratio

na

l Mo

nito

ring


Best practice in regulation raises the bar for all and reduces risks

Tighten injection regulations generally

Strong models of regulation exist

currently within the UIC. These should be

applied broadly, including to Class II

injectors:

• Class I/II Fractured Injection in

Alaska’s “Grind-and-Inject” facilities

• Class V Fractured Injection of biosolids

at Los Angeles Terminal Island Waste

Water Treatment Plant

These models generally require

technically rigorous demonstration of

safe operations using a combination of

scientific and physical observation

techniques along with muscular

reporting requirements

Broaden application of fractured injection

Encourage state level regulators to

establish guidelines for Class II fractured

injection potentially alongside no pit

rules (i.e., as in New Mexico, Alaska)

Expand use of fractured injection for

other sludge / semi-solid waste streams

which present challenges to traditional

infrastructure:

• Non-Hazardous (i.e., food)

• Haz (i.e., biosolids, mining, refinery,

pipeline, chemical plant wastes)

These wastes continue to present

significant challenges to their safe

disposal which can be addressed under

the UIC with appropriate consideration

to safe injection best practices


Final thoughts

Fractured injection provides high value use of UIC wells

1. Addresses serious disposal needs in specialized environments

2. Some state UIC permit rules provide insufficient operating windows for

fractured injection techniques

3. Users hesitant to advance “experimental” projects mistakenly believing

that they provide insufficient certainty for long term operations

4. Balanced monitoring and reporting requirements are in place for some

injected solids projects and can serve as a model for future installations

• Class I/II solids injection in Alaska's "grind-and-inject" facilities

• Class V biosolids injection in Los Angeles

Clarification within UIC local rules could assist in unlocking the potential of solids

injection to address several challenging waste types, including biosolids


Thank You

Advantek International11000 Richmond Avenue suite 190

Houston, Texas, 77042

713.532.7627

[email protected]

www.advantekwms.com

Documents

Fractured Injection Design and Monitoring - gwpc.org REVISED_0.pdf · Fractured Injection Design and Monitoring Omar Abou-Sayed ... Mixing Tank 4. Electric Pumps 5. ... storage volume,