July 2013 Fracturing Fluids from Produced Water

Public Disclosure (North America)

Tremendous growth in public

awareness related to shale

development in the past several

years

Public asked what we were doing

and we were not ready to answer

Media and the public have

focused on how harmful the

fracturing process can be

Public Disclosure (North America)

Misinformation:

Controversial drilling technique

We use water, sand and a lot

of chemicals

We use millions of gallons of

water and hundreds of tons of

chemicals

Cocktail of toxic and

carcinogenic chemicals

We blast fluid laced with

chemicals

Fast Facts

Fracture stimulation is a safe and proven technology

Used for more than 60 years in more than 1 million applications

Used to safely and effectively recover natural gas from hard-to-produce resources trapped in deep shale and other unconventional formations deep below ground

No confirmed cases of drinking water contamination

Fracture stimulation is KEY to

releasing America’s abundant

domestic supply of clean-burning

natural gas

Will be required for 60 to 80% of

wells drilled in the US during the

next decade

Public Disclosure

Only a relatively small volume of chemical additives are present in fracturing

fluids (0.79%) with water and sand making up around 99.2%

In addition to federal right to know laws, many states have passed laws

requiring full chemical disclosure

Even in states where reporting is not a state requirement, disclosure reports

are voluntarily provided by oil and natural gas operators

To date more than 42,000

chemical disclosure reports have

been filed on FracFocus for

hydraulically fractured wells

Goal of Presentation

Present the development of a new crosslinked gel system based in guar derivative that can be used in flowback or produced water

Show laboratory testing of the fluid characteristics in untreated produced water from the Bakken and the outcome of hybrid fluids, including field testing

Present new FR technology for untreated water.

Classification of Water Type Based on

Total Dissolved Solids (TDS) Concentration

(Downey and Armstrong, 1977)

Water Source TDS Concentration TDS Concentration (mg/L)

Fresh < 1,000

Slightly Saline 1,000-3,000

Moderately Saline 3,000-10,000

Saline 10,000-35,000

Sea Water > 35,000

Produced (Bakken Formation)

Williston Basin North Dakota 220,000-350,000

Water Handling Costs in the Bakken

Formation within the Williston Basin

Source: Evaluation of Brackish Ground Water Treatment for Use in Hydraulic Fracturing of the Bakken Play, North Dakota. Report 2011-

EEC-12-05, Energy and Environment Research Center University of North Dakota, Grand Forks, ND (December 2011)

Cost

$/bbl

Cost

$/1,000 gal

Acquisition Cost

Raw Water $0.25-$1.05 $5.95-$25.00

Transportation $0.63-$5.00 $15.00-$119.05

Disposal Cost

Transportation $0.63-$9.00 $15.00-$214.00

Deep Well Injection $0.50-$1.75 $11.90-$41.66

Total Cost $2.00-$16.80 $47.62-$400.00

What is Going on with Flowback and Produced Water?

In general, flowback and produced water

samples have total dissolved solids (TDS)

levels ranging from 80,000 to 350,000 mg/L

Divalent cation levels, such as Ca, Mg, Ba, Sr

and Fe, can be as high as 40,000 mg/L Analysis Date:

Location: Analyst:

Formation: Sample Point:

BHT: Sample Date:

Well Type:

Phosphate

Silica

Chromium

Bakken Produced Water

5.12

Not PresentH2S

48.80

0.00

Iron

Manganese

meq/Lmg/L

21.72

75720.00

14750.00

1263.00

7.63

951.80

109.20

9.72

File:

pH

Hydroxide

Carbonates

Bicarbonates

0.00 0.00

Magnesium

Barium

Strontium

Potassium0.00

0.00

Sulfate

Chlorides 153860.50

580.30

Sodium

Calcium

mg/LAnions meq/L Cations

0.53

5.86

13.11512.30

0.11

103.94

737.50

3293.824338.87

12.07

0.80

0.00

0.00 0.00

0.00

Comments:

Specific Gravity = 1.163 and Boron conc. = 276.9 mg/L

Untreated Water

Typical Water Analysis Produced Water Bakken (North Dakota)

Trican’s New Crosslinked Gel System Based in Guar

Derivative in Produced Water from the Bakken – North Dakota

Produced water

Bakken ‒ North Dakota

Crosslinking Guar Derivative System

Untreated Produced Water

Bakken – North Dakota

Crosslinked Guar Derivative System

Untreated Produced Water

Bakken – North Dakota

Rheological Profile of New Guar Derivative

Gel System at Different Temperatures

0

200

400

600

800

1000

1200

1400

0 20 40 60 80 100 120

Vis

co

sit

y, 4

0/s

, R

1B

2, (c

P)

Time (Minutes)

Temp. 240 °F

Temp. 225 °F

Temp. 200 °F

Temp. 180 °F

20# Crosslinked System in Bakken Untreated Produced Water at Different Temperatures

Trican Water Analysis Report

Sample ID PH SG Na K Ca Mg B Mn Sr Fe Ba F- Cl- NO3- HCO3- PO4 SO4 2-

mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L mg/L

Untreated Water 6.65 1.046 65,580 522.9 30,360 1,333 367.7 15 1,763 95.72 20 ND 192,072 26.5 524 ND 211.9

Rheological Profile of New Guar Derivative Gel System @ 240°F

Previous Hydration at Different Temperatures (Box Time 9 min)

0

200

400

600

800

1000

1200

1400

1600

0 10 20 30 40 50 60

VIS

CO

SIT

Y, 4

0/S

, R

1B

2,

(cP

)

Time (Minutes)

9 Min. Box Time, 70°F hydration Temp.



9 Min. Box Time, 40°F hydration Temp.Temp

(°F)

Viscosity

Linear Gel @

9 min

Hydration

Time

40 25.3

50 27.9

60 25.1

70 23.0

25# Crosslinked System in Bakken Untreated Produced Water





Rheological Profile of New Guar Derivative Gel System @ 240°F

Previous Hydration at Different Temperatures (Box Time 3 min)

0

200

400

600

800

1000

1200

1400

1600

0 10 20 30 40 50 60

VIS

CO

SIT

Y, 4

0/S

, R

1B

2,

(cP

)

Time (Minutes)



3 Min. Box time, 50°F hydration Temp.



Temp

(°F)

Viscosity

Linear Gel @

3 min

Hydration

Time

40 6.3

50 15.6

60 16.7

70 17.6





Breaking Profile of New Guar

Derivative Gel System @ 250°F

0

50

100

150

200

250

300

0

200

400

600

800

1000

1200

1400

1600

0 10 20 30 40 50 60 70 80 90 100 110 120

Te

mp

era

ture

(°F

)

Vis

co

sit

y, 4

0/s

, R

1B

2, (c

P)

Time (Minutes)

30 lb/1000 gal Baseline

30 lb/1000 gal Baseline + 0.50 lb/1000 gal Breaker

Temperature






Size of Colloids in Solution of Broken Guar Derivative Gels

in Produced Water vs. Broken Guar Gels in Fresh Water

20 lb/1,000gal

25 lb/1,000 gal

30 lb/1,000 gal

1 10 100 1000 10000size distribution (nm)

Size Distribution of Broken New Guar Derivative Gel Systems in Produced Water after aged for 16 hr @ 240°F

100%

4.2%

19.2%

92%

76.8%

95.7%

20lb/1000gallons

25lb/1000gallons

30lb/1000gallons

3.9%

4%

4.3%

1 10 100 1000 10000size distribution (nm)

Size Distribution of Broken of Guar Gel Systems in Fresh Water after aged for 16 hr @ 240°F

What We Look for with Slickwater Systems

Comparison of Enhanced Friction Reducers

in High Salinity Brine

Anionic FR

Anionic FR Plus

Cationic FR Plus

Cationic FR

Effect of 1 gpt Anionic FR, Cationic, Cationic w/ Enhancer

Friction Reduction in 3/8 in. Pipe @ 72°F and Re#=174,000 in Synthetic Brine with 251K ppm TDS (153K ppm Chloride, 20K ppm

Calcium and 78K ppm Sodium)

Field Testing of Crosslinked

System in the Bakken

A field test was performed on two wells with a total of 52 fracturing

stages using 100% produced water

Estimated BHST was 246°F and pump rates between 20 and 35 bbl/min

through 4.5-4.0 ID casing in openhole perforations with sliding sleeves

Polymer loading of the guar derivative gel system was varied between

20 and 30 lb/1,000 gal

Slickwater using 1 gal/1,000 gal of enhanced FR

Total pumped proppant:

352K lb 100 mesh sand

1.726 million lb 30/50 ‒ 20:40 sand

434K lb 30/50 CRC

Total volume of produced water used in both wells was close to 3

million gallons

Questions?

Thank you.

July 2013 Fracturing Fluids from Produced Water

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