Presentation - Halliburton

Environmentally Focused Innovative 

Fracturing Fluids 

Jason Bryant 

Environmental Solutions Tenet Manager

Hydraulic Fracturing…. in the Spotlight 

© 2012 HALLIBURTON. ALL RIGHTS RESERVED. 

2 

circa April 2011

EPA's study of hydraulic fracturing and its potential 

impact on drinking water resources 

• At the request of Congress, EPA is conducting a study to better 

understand any potential impacts of hydraulic fracturing on drinking 

water and ground water. The scope of the research includes the full 

lifespan of water in hydraulic fracturing, from acquisition of the water, 

through the mixing of chemicals and actual fracturing, to the postfracturing 

stage, including the management of flowback and 

produced water and its ultimate treatment and disposal. 

• A first report on the study will be released for peer review in late 

2012. Certain portions of the research will be released for peer 

review in 2014. 


3

EPA to Investigate Effects of Hydraulic Fracturing 

• Natural gas plays a key role in our nation's clean energy future. The U.S. has 

vast reserves of natural gas that are commercially viable as a result of 

advances in horizontal drilling and hydraulic fracturing technologies enabling 

greater access to gas in shale formations. Responsible development of 

America's shale gas resources offers important economic, energy security, 

and environmental benefits. 

• EPA is working with states and other key stakeholders to help ensure that 

natural gas extraction does not come at the expense of public health and the 

environment. The Agency's focus and obligations under the law are to 

provide oversight, guidance and, where appropriate, rulemaking that achieve 

the best possible protections for the air, water and land where Americans live, 

work and play. The Agency is investing in improving our scientific 

understanding of hydraulic fracturing, providing regulatory clarity with respect 

to existing laws, and using existing authorities where appropriate to enhance 

health and environmental safeguards. 


4



http://www.epa.gov/hfstudy/HF_Study__Plan_110211_FINAL_508.pdf 


5



100% Water Recycle 



6





Environmental Chemicals 


7

Frac Fluid Composition 

*Image: EnergyinDepth.org 2009 Source: Compiled 

from Data collected at a Fayetteville Shale Fracture 

Stimulation by ALL Consulting 2008. 

Environmental Chemicals 100% Water Recycle 


8

Large Amounts of Water 

55% 

28% 

Wood, Ruth et al. Shale Gas: A Provisional Assessment of Climate Change and Environmental Impacts. 

January 2011. New York State (2009) Supplemental generic environmental impact statement on the oil, 

gas and solution mining regulatory program’ by the New York State Department of Environmental 

Conservation Division of Mineral Resources. 



9

Large Amounts of Water 



10

Water Management: Field-Scale Issue 

Water Needed vs. Produced 

per Well in Field’s Completion Program 

• Municipal Fresh Water 

• Surface Waters 

– Rivers 

– Lakes 

– Sea water 

• Ground Water 

– Aquifers 

– Water sheds 

• Waste water 

– Municipal 

– AMD 



11

Handling Flowback / Produced Water (FBPW) 

1) Use 

Processed 

Water 

2) Use 

Unprocessed 

Water 

FBPW 

FBPW 

Process 

Develop 

Frac 

Fluid 

Waste 

Clean 

Water 

Frac Fluid 

FBPW 



12

Flowback and Produced Water Variability 

Sample #1 #2 #3 #4 #5 #6 #7 #8 #9 

Specific gravity 1.026 1.036 1.019 1.012 1.070 1.100 1.170 1.105 1.066 

pH 7.92 7.51 7.91 6.61 6.72 6.68 6.05 7.11 7.04 

Ionic Strength 0.59 0.881 0.319 0.199 1.919 2.794 4.96 2.874 1.754 

Hydroxide (mpL) 0 0 0 0 0 0 0 0 0 

Carbonate (mpL) 0 0 0 0 0 0 0 0 0 

Bicarbonate (mpL) 1,010 717 1190 259 183 183 76 366 366 

Chloride (mpL) 19,400 29,400 10,000 6,290 59,700 87,700 153,000 96,400 58,300 

Sulfate (mpL) 34 0 88 67 0 0 0 670 749 

Calcium (mpL) 630 1,058 294 476 7,283 10,210 20,100 4,131 2,573 

Magnesium (mpL) 199 265 145 49.6 599 840 1,690 544 344.0 

Barium (mpL) 49.4 94.8 6.42 6.24 278 213 657 1.06 5.1 

Strontium (mpL) 107 179 44.7 74.3 2,087 2,353 5,049 178 112 

Total Iron (mpL) 4.73 25.7 8.03 14 27.4 2.89 67.6 26.4 33.8 

Aluminum (mpL) 0.17 0.21 0.91 0.38 0.18 0 0.1 0.17 0.78 

Boron (mpL) 28.2 27.1 26.7 8.82 45.1 73.1 80.4 94.5 65.7 

Potassium (mpL) 192 273 78.7 85.8 977 1,559 2,273 2,232 1,439 

Sodium (mpL) 10,960 16,450 5,985 3,261 26,780 39,990 61,400 54,690 32,600 

TDS (mpL) 33,300 49,300 18,200 10,800 98,600 144,000 252,000 160,000 97,700 

TSS (mpL) 57 246 50 30 10 12 32 120 13,762 

TOC (mpL) 89 64 133 180 218 70 143 266 235 



13

Fracturing Fluids with Produced Waters 

• Friction Reducers 

– Minimize pipe friction, surface 

treating pressure and horsepower 

– Maximize rate and bottom hole 

treating pressure 

– Impacts: poor sustained friction 

reduction performance and higher 

scaling tendencies 

• Crosslinked Fluids 

– Minimize pipe friction, surface 

treating pressure and horsepower 

– Adequate fracture width, proppant 

placement, and fracture cleanup 

– Impacts: high friction, screenouts, 

low conductivity, and higher 

scaling tendencies 

Courtesy of the Flow Assurance and Scale Team (FAST) JIP at Heriot-Watt and Leeds Universities 



14

Will a High TDS Fluid Damage my Well? 

Na + 

K + (if not known =0) 

Mg 2+ 

Ca 2+ 

Sr 2+ 

Ba 2+ 

Fe 2+ 

Cl - 

SO 

4 2- 

Alkalinity** 

TDS (Measured) 

Calc. Density (STP) 

pH, measured (STP) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(mg/l) 

(g/ml) 

pH 

Brine 1 

54,690 

2,232 

544 

4,131 

178 

1 

26 

96,400 

670 

366 

160,000 

1.100 

7.11 

Brine 2 

61,400 

2,273 

1,690 

20,100 

5,049 

657 

68 

153,000 

0 

76 

252,000 

1.157 

6.05 

Brine 3 

10,960 

192 

199 

630 

107 

49 

5 

19,400 

34 

1,010 

33,300 

1.020 

7.92 

Brine 4 

39,990 

977 

840 

10,210 

2,353 

213 

3 

87,700 

0 

183 

144,000 

1.093 

6.68 

Reference Municipal 

Water 

40 

7 

25 

37 

1 

0 

0 

47 

118 

162 

440 

0.997 

7.41 



15

Scaling Tendencies 

Potential Scale (lb/1,000bbl) 

160 

140 

120 

100 

80 

60 

40 

20 

0 

Bakken Marcellus 1 Woodford Marcellus 2 

Brine 1 Brine 2 Brine 3 Brine 4 

Siderite 

Barite 

Calcite 

(FeCO 3 ) 

(BaSO 4 ) 

(CaCO 3 ) 



16

Potential Scale (lb/1,000bbl) 

If You Mix With The Wrong Water… 

(50/50 with reference tap water) 

160 

140 

120 

100 

80 

60 

40 

20 

0 

Brine 1 Brine 1 

+ 


+ 


+ 


+ 

reference 

reference 

reference 

reference 

municipal 

municipal 

municipal 

municipal 

water 

water 

water 

water 

Celestite 

Anhydrite 

Siderite 

Barite 

Calcite 

(SrSO 4 ) 

(CaSO 4 ) 

(FeCO 3 ) 

(BaSO 4 ) 

(CaCO 3 ) 



17

Friction Reducers: Effects of Ca 2+ on Standard FRs 

% Friction Reduction 

-20 

-10 

0 

10 

20 

30 

40 

50 

60 

70 

80 

90 

100 

ppm Calcium 

0 

0 2 4 6 8 10 12 14 16 18 

Time (minutes) 



18



-20 

-10 

0 

10 

20 

30 

40 

50 

60 

70 

80 

90 

100 

ppm Calcium 

0 

50 

100 

200 

400 

600 

1000 

1500 

2000 

0 2 4 6 8 10 12 14 16 18 




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-20 

-10 

0 

10 

20 

30 

40 

50 

60 

70 

80 

90 

100 

% Reduction vs. Time in 1/2-in Smooth Pipe 

Looking at effects of Ca 2+ on 2.5 lb/Mgal of Anionic FR 

ppm Calcium 

0 

50 

100 

200 

400 

600 

1000 

1500 

2000 

4000 

10,000 

16,000 

22,000 

27,500 

34,000 

43,300 

52,400 

0 2 4 6 8 10 12 14 16 18 




20

Time-Average % Friction Reduction 

100 

90 

80 

70 

60 

50 

40 

30 

20 

10 

Friction Reducers: Effects of Other Constituents on 

Standard FRs 

0 

TDS = 10,800 mpl; 

TH = 600 mpl 

TDS = 17,700 mpl; 

TH = 500 mpl 

TDS = 33,300 mpl; 

TH = 1000 mpl 

TDS = 98,600 mpl; 

TH = 10,200 mpl 

TDS = 144,000 mpl; 

TH = 13,600 mpl 

TDS = 166,000 mpl; TDS = 252,000 mpl; 

TH = 4,900 mpl TH = 27,500 mpl 

1-Minute 

4-Minutes 

25-Minutes 

Lines: 

1 gpt 

Anionic FR 

in Fresh 

Water, the 

benchmark 



21

Friction Reducers: Salt-Tolerant Friction Reducers 

FR-98, 0.1 gpt MC B-8642, 0.2 gpt MC 5-2510T, 

0.5 gpt Lo-Surf 300 

FR-98 

>200,000 mpl TDS water 



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Friction Reducers: Salt-Tolerant Friction Reducers 

Suite of Friction Reducers 

Enables 100% Produced Water reuse 

Maintains Freshwater Performance 

Tolerant of high levels of multivalent cations 

Tolerant of a variety of unknown contaminants 

Friction Reducer 

TDS (mpl) 

FR-78 50,000 to 100,000 

FR-88 100,000 to 200,000 

FR-98 More than 200,000 

Field Trial: FR-98 in 250,000 mpl TDS Water, 100 bpm, 4.5-in. casing 



23

Crosslinked Fluids: Behavior in Produced Water 

Viscosity / cp @ 40 s -1 

2000 

1800 

1600 

1400 

1200 

1000 

800 

600 

400 

200 

0 

Mixed Water (80 Fresh: 20 Produced) 

Original Formula 

0 10 20 30 40 50 60 70 80 90 

Time / min 

100% fresh water 

Original Formula 

Mixed Water (80 Fresh: 20 Produced) 

Modified Formula 

250 

200 

150 

100 

50 

0 

Temperature / F 



24

Summary: 100% Water Recycling 

• Scale Program is essential 

–Standard water analysis for all waters 

–Formation, Fracturing, and Production conditions 

–Scale Inhibitors may be necessary 

• Friction Reducers 

–FR-78, FR-88, FR-98 

–Enables 100% Produced Water reuse 

–TDS > 200,000 mpl 

• Crosslinked Fluids 

–100% Produced Water reuse requires formulation 

adjustments 

–Fracturing Fluid Knowledge: crosslinking and 

breaking 



25

Groundwater Contamination: Effects from Hydraulic 


Wood, Ruth et al. Shale Gas: A Provisional Assessment of Climate Change and Environmental Impacts. January 2011. 

US EPA Hydraulic Fracturing Research Study – Scoping Backgrounder, 2010. 

State Oil and Gas Regulations Designed to Protect Water Resources – Groundwater protection Council, US Dept. of Energy, 

National Energy Technology Laboratory May 2009 


26

Groundwater Contamination: Effects from Hydraulic 


The API study analysed the risk of contamination from properly constructed 

Class II injection wells to an Underground Source of Drinking Water 

(USDW) due to corrosion of the casing and failure of the casing cement 

seal. Using this, the ICF study (and New York State, 2009) identified that 

the “probability of fracture fluids reaching a USDW due to failures in the 

casing or casing cement is estimated at less than 2 x 10-8 (fewer than 1 in 

50million wells)”. On this basis the ICF study concludes that “hydraulic 

fracturing does not present a reasonably foreseeable risk of significant 

adverse environmental impacts to potential freshwater aquifers” 


New York State (2009) Supplemental generic environmental impact statement on the oil, gas and solution mining regulatory 

program’ by the New York State Department of Environmental Conservation Division of Mineral Resources. 


27

Green Technologies: Fracturing Fluid Chemistries 

Chemical Group 

Gelling Agent 

Hydration Aid 

Biocide 

Crosslinker 

Breaker 

Surfactant 

Function 

Reduce friction, Fluid viscosity modification 

Control bacteria growth; Fracturing Fluid integrity 

and Formation health 

Increase Fracturing Fluid viscoelasticity; Proppant 

transport and distribution 

Reduce Fracturing Fluid viscoelasticity and viscosity; 

Fracture cleanup 

Enhance hydrocarbon recovery 


28

Green Technologies: Fracturing Fluid Chemistries 


http://www.halliburton.com/public/projects/pubsdata/Hydraulic_Fracturing/fluids_disclosure.html 


29 

Environmental Chemicals

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

Green Technologies: Advanced Dry Polymer (ADP) 

Blender 

• Batch Hydration: Solids (50’s) 

Hydration in Hours 

Tedious, Time-Consuming Operation 

Requires Large Physical Footprint 

Susceptible to Bacteria Contamination 

• On-the-Fly: LGC’s (70’s) 

Hydration in seconds 

(70’s) Aqueous Carriers; 15% active 

(80’s) Hydrocarbon Carriers; 50% active 

Diesel; BETX 

• On-the-Fly with Solids (00’s) 

Hydration in Seconds 

High-Energy Fluid Shearing Device 

Capable of High Throughput Rates 




30

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

Green Technologies: CleanStream ® Service 

DNA before exposure 

DNA after exposure 

• Ultraviolet (UV) Light reduces 

and controls bacteria levels 

Damages Bacteria DNA 

Renders Bacteria Sterile 

Viable Bacteria are Reduced by 

99.99% 

• UV Reduces Chemical 

Biocides 

Many Applications are Biocide-Free 

• UV is Field Tested and 

Proven 

High Throughput Rates 

Various Water Qualities and 

Turbidities 




31

Green Technologies: CleanStim ® Hydraulic Fracturing 

Fluid System 

Enzyme 

Constituent 

Exthoxylated Sugar-Based 

Fatty Acid Ester 

Inorganic Acid 

Inorganic Salt 

Maltodextrin 

Organic Acid 

Organic Ester 

Partially Hydrogenated 

Vegetable Oil 

Polysaccharide Polymer 

Sulfonated Alcohol 

Common Uses 

Soybean Paste, Fruit Juices and Nectars, Laundry Detergent, Dishwasher 

Detergent, Toilet Cleaner, Industrial Pulp and Paper Processing Aid 

Synthetic Food Flavoring Substance, Natural Baby Wipes, Baby Wash and 

Shampoo 

Cheese, Alcoholic Beverages, Wheel Cleaner, Rust Dissolver, Dishwashing 

Detergent 

Food Starch – Modified, Water Clarifier, Fish Tank Water Treatment 

Sweetener, Glaze and Icing Sugar, Coconut Milk and Coconut Cream, 

Shower Gel 

Fruit Juice, Dishwasher Cleaner, All-Purpose Cleaner, Hand Soap 

Liquid Egg Products, Food Resinous and Polymeric Coatings, Hairspray 

Confectionary Chocolate Coating, Hair Detangler, Body Lotion, Lip Liner, 

Soap, Lotion, Cream and Other Skin Care Formulations 

Canned Fish, Processed Cheese, Dairy-Based Desserts and Drinks, Beer, 

Toothpaste 

Egg White Solids, Marshmallows, Dishwashing Liquid, Home Dilutable 

Cleaner, Shampoo, Acne Scrub, Shaving Cream, Liquid Hand Soap 




32


Fluid System 

Component 

CleanWG 

CleanLink 

CleanSurf 

CleanBreak E 

Function 

Polysaccharide gelling agent 

Crosslinker 

Surfactant 

Conventional enzyme 


CleanBreak CRE 

CleanBreak LT 

CleanBreak MT 

CleanBreak HT 

CleanBreak XT 

Controlled-release enzyme 

Encapsulated Breaker 

Triggered-release breaker 

Triggered-release breaker 

Breaker 



33


Fluid System 

Base Gel Hydration 




34


Fluid System 

Crosslinked Fluid Rheology 




35


Fluid System 





36


Fluid System 





37


Fluid System 

Broken Gel Comparison 


CleanStim ® 

60 lb/1000gal 

Guar-Borate 

25 lb/1000gal 

Both gels broken with enzyme breakers 



38


Fluid System 

% Regain Conductivity 

120 

100 

80 

60 

40 

20 

0 

Regained Conductivity 

CleanStim Fracturing Fluid Regain Conductivity with Breakers 

1 lb/ft 2 Ottawa Sand between Ohio Sandstone Cores; 2000 psi Closure Stress 

2% KCl before wet gas 

wet gas 

2% KCl after wet gas 

1.25 lb CleanBreak E 1.5 lb CleanBreak CRE 5 lb CleanBreak LT 10 lb CleanBreak MT 10 lb CleanBreak HT 1 gal CleanBreak XT 1 gal CleanBreak XT 

40 lb CleanWG 40 lb CleanWG 40 lb CleanWG 60 lb CleanWG 60 lb CleanWG 60 lb CleanWG 60 lb CleanWG 

120 °F 120 °F 120 °F 140 °F 160 °F 180 °F 200 °F 

Holtsclaw J., Loveless D., et al. Environmentally Focussed Crosslinked-Gel System Results in 

High Retained Proppant-Pack Conductivity. SPE 146832, ATCE, Denver 2011 




39


Fluid System 

% Retained Conductivity 

110 

100 

90 

80 

70 

60 

50 

40 

30 

20 

10 

0 

2000 psi (0 h) 

2000 psi (10 h) 

200 °F 

140 °F 

120 °F 

2 mL/min 

flow 

2000 psi (15 h) 

2000 psi (20 h) 

2000 psi (23 h) 10 mL/min 

Regained Conductivity, 3 rd Party 

2000 psi (24 h) 20 mL/min 

2000 psi (25 h) 25 mL/min 

Wet gas flow 

2000 psi (40 h) after wet gas 

2000 psi (50 h) after wet gas 

105% 

95% 

74% 




40


Fluid System 

Xlinked gel 

Proppant Transport 

1 ppg 20/40 Ottawa 


5 ppg 20/40 Ottawa 

Xlinked gel after sand 

through system 

Loveless D., Holtsclaw J., et al. Fracturing Fluid Comprised of Components Sourced Solely from the 

Food Industry Provide Superior Proppant Transport. SPE 147206, ATCE, Denver 2011 



41


Fluid System 

Proppant Transport 


SFI Gel 

Linear Gel 

VES Gel 



42

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 

̶ 


Fluid System 

• The Challenges 

Vertical (multistage) 

Horizontal (multistage) 

17,000 ft MD; 12,000 ft TVD 

Shales 

Sandstones 

Gas reservoirs 

Oil reservoirs 

• 120 to 340 °F BHST 

• 20 to 80 bbl/min 

• 3.5 in tubing to 5.5 in casing 

• Up to 7 lb/gal sand 

• Good Results 


Jobs To-Date 

Modeland N., Tomova I., et al. Using Enhanced Fracturing-Fluid Cleanup and Conductivity in the 

Hosston/Travis Peak Formation for Improved Production. SPE 150958, HFTC, The Woodlands 2012. 

43 


Environmental Chemicals

Fracturing Fluid Solutions for Your Water Concerns 

Provide Stimulation Solutions 

Resonates with the public 

Stays a step ahead of forthcoming regulations 

Provides greater enhancement efficiencies 

Fracturing Fluid Solution 

Suite of Salt-Tolerant Friction 

Reducers (FR-78, FR-88, FR-98) 

CleanStream ® Service 

Advanced Dry Polymer (ADP) 

Blender 

CleanStim ® Hydraulic Fracturing 

Fluid System 

Solving Challenges. 

Enables 100% Flowback/Produced 

without Treatment 

Reduces the Need for Chemical 

Bacteria Control 

Eliminates BETX Uncertainty with 

Gelling Agents 

Fracturing Fluid Formulation Made 

with Ingredients Sourced from the 

Food Industry 


44

Fracturing Fluid Solutions for Your Water Concerns 

Provide Stimulation Solutions 

Resonates with the public 

Stays a step ahead of forthcoming regulations 

Provides greater production enhancement efficiencies 

Fracturing Fluid Solution 

Suite of Salt-Tolerant Friction 

Reducers (FR-78, FR-88, FR-98) 

CleanStream ® Service 

Advanced Dry Polymer (ADP) 

Blender 

CleanStim ® Hydraulic Fracturing 

Fluid System 

Solving Challenges. 

Enables 100% Flowback/Produced 

without Treatment 

Reduces the Need for Chemical 

Bacteria Control 

Eliminates BETX Uncertainty with 

Gelling Agents 

Fracturing Fluid Formulation Made 

with Ingredients Sourced from the 

Food Industry 


45

On the Horizon… Air Quality 

Conventional resources generally exist in discrete, well-defined subsurface 

accumulations (reservoirs), with permeability values greater than a specified 

lower limit. Such conventional gas resources can usually be developed using 

vertical wells, and often yield economic recovery rates of more than 80% of 

the Gas Initially in Place (GIIP). By contrast, unconventional resources are 

found in accumulations where permeability is low. Such accumulations 

include “tight” sandstone formations, coal-beds, and shale formations. 

Unconventional resource accumulations tend to be distributed over a much 

larger area than conventional accumulations and usually require well 

stimulation in order to be economically productive; recovery factors are much 

lower — typically of the order of 15% to 30% of GIIP” (MIT, 2010). 


MIT (2010) The future of natural gas, an interdisciplinary study the Massachusetts Institute of Technology’s Energy Initiative 

ISBN (978-0-9828008-0-5 Copyright MIT 2010. 


46

On the Horizon… Air Quality 


DUKES (2010), Digest of UK Energy Statistics, Annex A. Department for Energy and Climate Change, London. 

POST (2005), Cleaner Coal postnote 253. Parliamentary Office of Science and Technology. 


47

On the Horizon…Air Quality 



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