OILFIELD CHEMICALS
PORTFOLIO
Sasol Performance Chemicals
About Us
Oilfield Chemicals Portfolio
About Us
Sasol Performance Chemicals develops and markets a broad portfolio
of organic and inorganic commodity and specialty chemicals
and comprises three key business divisions: Organics, Advanced
Materials and Wax. Our offices in 18 countries serve customers
around the world with a multifaceted portfolio of state-of-the-art
chemical products and solutions for a wide range of applications and
industries.
Surfactants, surfactant intermediates, fatty alcohols, linear alkyl benzene (LAB), shortchain linear alpha olefins, mineral oil-based and synthetic paraffin waxes, high-purity and
ultra-high-purity alumina as well as high-quality carbon solutions form the basis of our key
product range.
As individual as the industrial applications they serve, the tailor-made solutions offered by
our products create real business value for customers. Ongoing research activities result
in a continuous stream of innovative product concepts that help our customers position
themselves successfully in future markets.
Our products are used in countless applications in our daily lives to add value, security and
comfort. Typical examples include detergents, cleaning agents, personal care, construction,
paints, inks and coatings, metalworking and lubricants, hot-melt adhesives, bitumen
modification and catalyst support for automotive catalysts and refineries as well as other
specialty applications including oil and gas recovery, agriculture, plastic stabilization, and
polymer production. Every day, our researchers explore ways to improve our products and
develop innovations that improve the quality of people’s lives.
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Contents
Oilfield Chemicals Portfolio
Contents
1. Sasol’s Alcohol Portfolio........................................ 4
2. Sasol’s Surfactant Portfolio.................................. 6
3. Sasol Oilfield Chemicals Summary........................ 7
4. Sasol Products for Drilling and Completion......... 8
4.1 Base Oil Summary....................................................................... 9
4.2 HF 1000 Solvent ..................................................................... 10
4.3 LPA Solvent.............................................................................. 12
4.4 ODC Solvents............................................................................ 15
4.5 Wellbore Cleaner...................................................................... 16
4.6 Defoamer................................................................................. 17
5. Sasol Products for Oil Production.......................18
5.1 Foamer..................................................................................... 19
5.2 Binder....................................................................................... 20
5.3 High-Efficiency Concentrated Acid Solubiliser....................... 22
5.4 Flowback Agent....................................................................... 23
5.5 Heavy Oil Viscosity Reducer.................................................... 25
5.6 Paraffin and Asphaltene Dispersant....................................... 26
5.7 Intermediate Pour Point Depressants for the Oil Industry... 27
5.8 Easier-to-Handle Intermediate Pour Point Depressants....... 30
6. Sasol’s Cleaning Products...................................32
6.1 Sludge and Drilling Cutting Cleaner ....................................... 33
7. Sasol Products for Enhanced Oil Recovery.........35
7.1 Surfactants for Chemical-Enhanced Oil Recovery.................. 36
7.2 Surfactants for Mooney Field ASP Flooding........................... 38
7.3 Surfactants for Thermal-Enhanced Oil Recovery................... 40
7.4 Sasol‘s Additives Improve CO2 Floods.................................... 42
3
Oilfield Chemicals Portfolio
Sasol’s Alcohol Portfolio
1. Sasol’s Alcohol Portfolio
Description
Sasol is a global producer of linear and branched alcohols from C6 to C32, using both
synthetic and natural-based feedstocks. Sasol has the largest portfolio of alcohol products
available. This allows the formulator to choose the specific alcohol structure that delivers
the best performance for the final oilfield product.
Product Portfolio
Type
~%
Linear
Carbon
Chain
ALFOL
NAFOL
NACOL
Ziegler,
oleochemical
100
Even
C6 to C28
SAFOL
FT oxo
alcohol
50
Odd & even
C12 to C13
Isotridecyl
alcohol
0
C13
Trade Name
MARLIPAL O13
ISALCHEM
LIAL
ALCHEM
ISOFOL
Typical Structure
OH
OH
OH
5
Oxo alcohol
50
Odd & even
C9 to C17
OH
95
Guerbet
alcohol
0
Even
C12 to C32
OH
4
Oilfield Chemicals Portfolio
Sasol’s Alcohol Portfolio
Product Introduction
Ziegler Alcohols – ALFOL, NACOL, NAFOL Alcohol
Sasol’s Ziegler alcohols are high-purity, petrochemical-based linear primary alcohol homologues with even-numbered carbon chains ranging from C6 to C26+. Of these, pure cuts
are called NACOL alcohols, and blends are called NAFOL alcohols. All Ziegler alcohols are
either colourless liquids or white solids under ambient conditions and are physically and
chemically equivalent to alcohols made from oleochemical sources. The typical Ziegler alcohol ethoxylates are biodegradable. A similar portfolio of single cuts and blends, produced in
the USA, is called ALFOL alcohols.
Natural Alcohols – NACOL, NAFOL Alcohol
Sasol offers linear natural alcohols made from coconut, palm kernel, rapeseed oils and
other natural oils. These products are offered under the NACOL and NAFOL trademarks.
Fischer–Tropsch Oxo Alcohols – SAFOL Alcohol
SAFOL 23 alcohol is produced in South Africa through the hydroformylation of olefins
obtained in the Fischer–Tropsch (FT) process. This alcohol is approximately 50 % branched
and 50 % linear. Because the majority of the branching is not in the C-2 position when
further derivatised, it reacts more like a linear alcohol.
Isotridecyl Alcohol – MARLIPAL O13 Alcohol
Sasol’s ITDA is based on a C12 olefin, which is prepared through the trimerisation of
n-butene. In contrast to an isotridecyl alcohol produced with other starting materials, ITDA
is 100 % C13 alcohol and has a unique, significantly milder odour.
Oxo Alcohols – LIAL, ISALCHEM, ALCHEM Alcohol
LIAL alcohols are oxo alcohols consisting of mixtures of linear and mono-branched primary
alcohols with alkyl chain distributions from 9 to 17 carbon atoms. LIAL alcohols are highpurity, clear liquids with very low odour. Their molecular structure helps retain their liquid
state at room temperature. LIAL alcohols are fully saturated, resistant to oxidation and
show excellent colour stability.
ISALCHEM alcohols are prepared from Sasol’s oxo alcohols (LIAL alcohols) through a
fractionation process that yields ≥ 90 % branched material. ISALCHEM alcohols are highpurity, clear liquids with very low odour. Their isomeric molecular structure results in lower
melting points compared to the blend.
ALCHEM alcohols are prepared from Sasol’s oxo alcohols (LIAL alcohols) through a fractionation process that yields ≥ 90 % linear material.
Guerbet Alcohol – ISOFOL Alcohol
Sasol’s ISOFOL alcohols are available in C12 to C32. Most are liquid at ambient temperature, whereas the corresponding saturated alcohols are solid. While unsaturated linear
alcohols start to solidify at approximately 10 °C, ISOFOL alcohols C12 to C18 remain liquid
even below 0 °C.
5
Surfactant Portfolio
Oilfield Chemicals Portfolio
2. Sasol’s Surfactant Portfolio
Description
Sasol Performance Chemicals is a leading global producer of surfactants, surfactant
intermediates, high-purity alumina and related specialty products. We can provide all kinds
of nonionic and anionic surfactants.
Register of Product Groups
1. Surfactants, nonionic, C6 to 32-based
2. Surfactants, anionic
• Alkylbenzene sulphonic acids
• Alkylbenzene sulphonates
• Alcohol sulphates
• Alcohol ether sulphates
• Alkyl-(aryl) alkoxylated carboxylic acids
6
Sasol Oilfield Chemicals Summary
Oilfield Chemicals Portfolio
3. Sasol Oilfield Chemicals Summary
Sasol products are manufactured around the globe to lower costs
and ensure supply chain robustness.
BTEX-free and
friction-reducing
base oils
Emulsifiers,
demulsifiers and
non-emulsifiers
Flow-back
surfactants
Defoamers
Paraffin/
asphaltene
inhibitors
Acid emulsifiers
Surfactants for
guar suspension,
viscosity
improvement
Drilling
Surfactants/solvents
for wellbore cleaning
Cementing
Foamers/surfactant
base materials for gas
well deliquification
Completion
Production
Foamers/surfactants
for removing paraffin
and asphaltenes
Dispersing aids for
cement additives
Stimulation
Enhanced
oil recovery
High-efficiency
primary surfactants
for ASP/SP flood
Foamers/surfactant
base materials for
foam-based drilling
Raw materials for
flow improvement
Surfactants for CO2
flood and SAGD
Co-surfactants
for ASP/SP flood
7
Oilfield Chemicals Portfolio
Sasol Products for Drilling and Completion
4. Sasol Products for Drilling
and Completion
8
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
4.1 Base Oil Summary
Description
Sasol’s ODC and LPA base oils are mixtures of isoparaffins and naphthenics. These solvents
are value-added alternatives in drilling fluids and fracturing applications because of their
low toxicity, improved biodegradability over diesel, the absence of polynuclear aromatics,
higher solvent strengths and lower pour points. HF 1000 is a synthetic base oil with native
olefins and esters that allow for a good lubricity profile to promote an enhanced rate of
penetration (ROP) in drilling operations.
Typical Properties
Biodegradation
GHS Environmental
Classification
Odour
Aromatics
Diesel
Mineral Oil
Sasol
ODC Solvent
Sasol
LPA Solvent
Sasol
HF 1000 Solvent
Inherently
Readily
Readily
Readily
Readily
Toxic to aquatic
life with longlasting effects
None
None
None
None
Strong
Moderate
Moderate
Moderate
Slight
30 to 50 %*
< 0.1 %*
<1%
<1%
Non-detect***
BTEX
< 1 %*
< 0.5 %*
Non-detect**
Non-detect**
Non-detect**
Flash point
– 61 °C
45 to 120 °C
~ 70 °C
63 to 107 °C
> 100 °C
Pour point
0 °C
(0# Diesel)
0 °C
(5# MO)
< –70 °C
–70 to –58 °C
–14 °C
70 °C
68 to 81 °C
66 °C
Density @ 20 °C
0.81 to 0.86
g/ml
0.80 to 0.82
g/ml
0.810
g/ml
0.8055 to 0.8271
g/ml
0.8045
g/ml
Kinematic
viscosity @ 20 °C
2 to 4 cSt
2.6 to 5.1 cSt
2.2 cSt
1.8 to 4.1 cSt
3.2 cSt
> 100 ppm
< 2 ppm
< 1 ppm
< 1 ppm
< 0.1 ppm
Non-synthetic
(derived from
kerosene)
Non-synthetic
(derived from
kerosene)
Aniline point
Sulphur
Production
process
Non-synthetic
Non-synthetic (derived
(derived from
from kerosene)
kerosene)
Mostly synthetic
> 50 % (nonkerosene-derived)
*
literature data
** detection limit 36 ppb
*** detection limit 0.1 ppm
9
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
4.2 HF 1000 Solvent
Description
Sasol’s HF 1000 solvent is a synthetic high-performance alternative to diesel fuel
and highly refined mineral oils. HF 1000 solvent is a value-added alternative in highperformance industrial applications because of its low acute aquatic toxicity, rapid
biodegradation and the absence of polynuclear aromatics. HF 1000 solvent is BTEX-free.
HF 1000 solvent is a blend of paraffin, olefins and oxygenates which combine to make a
low-viscosity, pale yellow liquid with a flash point of > 80 °C (175 °F).
Composition and Physical Properties
These properties may vary slightly from lot to lot due to normal manufacturing variability.
Property
Value
Aniline point, °C
Boiling point, °C
Property
Value
66
Flash point, °C
≥ 81
IBP
211
Pour point, °C
–14
5%
224
Vapor pressure, mm Hg @ 20 °C
0.3
95 %
346
EBP
364
Average molecular weight (amu)
Colour, APHA
210 to 220
< 100
Density, lbs/gal @ 16 °C
6.74
Specific gravity, @ 20 °C (68 °F)
API gravity, @ 16 °C
0.799
47
20 °C
3.23
40 °C
2.20
Auto-ignition temp., °C
248
Viscosity, cSt
VOC (EPA Method 24), %
74
Aromatics – BTEX, mg/kg
Non-detectable
PAH – polycyclic aromatic hydrocarbon (EPA Method 1654 ‘MI
Modified’)
Non-detectable
Applications
• Drilling fluids
• Stimulation fluids (slurry concentrates)
Advantages
•
•
•
•
•
•
10
Synthetic, contains isoparaffins, olefins, paraffins, esters and alcohols
No aromatics
Readily biodegradable and low acute aquatic toxicity
High flash point > 80 °C
Excellent lubricating property
Non-fluorescent
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
Environmental Profile: Aerobic Biodegradation
Biodegradation tests carried out in accordance with the OECD 301-F guideline show that
the HF 1000 solvent will exhibit > 60 % degradation by day 28. When tested together,
the HF 1000 solvent shows a more rapid and extensive biodegradation than the #2 diesel
fuel.
Environmental Profile: Aquatic Toxicity
HF 1000 solvent is only slightly soluble in water (~ 15 ppm). HF 1000 solvent demonstrates low acute aquatic toxicity to freshwater and marine species when tested as a
water-associated fraction (WAF). For example, tests on mysid shrimp reveal an LC50 on the
order of 257,000 ppm for no. 7 drilling fluid spiked with 3 % HF 1000 solvent (see Table 2).
When HF 1000 solvent is used in conjunction with low-toxicity esters in oilfield applications, the combined material will meet the leptocheirus toxicity and anaerobic biodegradation requirements set by the EPA for specific oilfield applications (see Table 2).
Figure 1:
Biodegradation of HF 1000 solvent
and #2 diesel fuel in accordance with
the OECD 301-F guideline
% technical CO2
100
50
HF 1000 solvent
#2 diesel
0
0
5
10
15
Days
20
25
30
Table 2: Environmental properties of HF 1000 solvent
50:50
Pass Level
HF 1000/Esters
Test
Organism
HF 1000
Acute, static 96-hour
toxicity test
Mysidopsis
bahia
257,000 ppm
LC50*
315,200 ppm
LC50**
> 30,000
ppm LC50
US EPA. FR 58(41):
12507-12513
Acute, static 10-day
sediment toxicity test
Leptocheirus
plumulosus
-
0.6
Ratio ≤
1.0
ASTM E 1367
N/A
-
0.8
Ratio ≤
1.0
Modified
ISO 11734
D. magna
100 % of the water accommodated fraction
(WAF = 100,000 ppm)
-
N/A
US EPA-821-R-02-012:
Section 9,
Method 2021
P. promelas
25.4 % of the
water accommodated fraction (WAF =
100,000 ppm)
-
N/A
US EPA-821-R-02-012:
Section 9,
Method 2000
275-day closed
bottle anaerobic
biodegradation test
for base fluids
Acute, static
48-hour LC50
Acute, static
96-hour LC50
Test Method
* Testing done on generic no. 7 drilling fluid with 3 % HF 1000 solvent
**Testing done on generic no. 7 drilling fluid with 3 % of a 50:50 blend of HF 1000 solvent and esters
11
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
4.3 LPA Solvent
Description
LPA solvents are high-purity mixtures of hydrotreated isoparaffins and naphthenics with
very low levels of polynuclear aromatics. They can be used in a wide array of applications,
including oilfield, cleaning products, metal rolling oils, coatings and mining chemicals.
These solvents are clear liquids with mild odour and high solvency. The unique process used
to manufacture these solvents produces low levels of normal paraffins. Consequently, LPA
solvents have higher solvent strengths and lower freezing points than competitive low
aromatic solvents with equivalent boiling ranges.
Physical Properties
All LPA solvents have a bromine number of < 0.2, a nitrogen and sulphur content of
< 1 ppm and a water content of < 50 ppm. Other physical properties are listed in the table
below. Actual properties may vary slightly from lot to lot.
Typical Properties
Distillation range, °C
LPA
LPA 142
LPA 150
LPA 170
LPA 210
IBP
186
192
198
214
240
10 %
193
193
202
220
242
240
204
218
223
258
95 %
248
207
221
226
266
EP
264
212
227
230
280
90 %
Method
ASTM D-86
Flash point, (Tag CC) °C
ASTM D-56
62
63
69
78
–
Flash point, (PM) °C
ASTM D-93
67
–
–
81
107
Pour point, °C
ASTM D-97
< –68
< –70
< –70
< –70
–58
Specific gravity, g/ml @ 15 °C
ASTM D-287
0.810
0.804
0.808
0.810
0.826
Density, lbs/gal @ 15 °C
ASTM D-287
6.76
6.71
6.74
6.76
6.89
API
166
156
164
172
193
EPA 8260B
ND*
ND*
ND*
ND*
ND*
Colour, Saybolt universal
ASTM D-156
+30
+30
+30
+30
+30
Relative evaporation rate
(n-butyl acetate e = 1)
ASTM D-3539
0.02
0.09
0.03
0.02
0.004
API, calc.
0.16
0.34
0.19
0.05
0.02
2.2
1.8
2.1
2.4
4.1
1.6
1.3
1.5
1.7
2.6
ASTM D-611
70
68
71
73
79
ASTM D-1133
32
34
32
31
29
Calculated
15.9
16.0
15.9
15.9
15.8
Average molecular weight (amu)
Aromatics – BTEX, ppm
Vapor pressure, torr @ 20 °C
Viscosity, cSt
at 20 °C
at 40 °C
Aniline point, °C
Kauri-butanol value
Solubility parameters (MPa)
* Detection limit 36 ppb
12
½
ASTM D-445
Oilfield Chemicals Portfolio
Sasol Products for Drilling and Completion
Applications
LPA solvents are excellent for use in oilfield chemicals, household/industrial cleaning
products, metal rolling oils, paints and coatings, pesticide formulations, paper and mining
chemicals and water treatment chemicals. LPA solvents also demonstrate exceptional
performance as chemical process solvents, degreasers, freeze point depressants, lamp oils,
lubricating oils and printing ink oils.
Advantages
•
•
•
•
•
Low aromatic aliphatic solvents
Various cuts range in flash point from 60 °C to 105 °C
Readily biodegradable
Meets certain FDA regulations for food contact
Low VOC alternative to mineral spirits
13
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
Environmental Profile: Aquatic Toxicity
LPA solvents are not acutely toxic to aquatic organisms. Below are the results of the waterassociated fraction test conducted in accordance with the US EPA method using freshwater
species (D. magna, O. mykiss and P. promelas) on LPA 170.
Test Results
LPA 170 (mg/L)
48-hour D. magna, LL50
> 100
96-hour O. mykiss, LL50
> 100
96-hour P. promelas, LL50
> 100
Environmental Profile: Aerobic Biodegradation
LPA 170 solvent biodegrades rapidly and extensively. At the end of the 28-day period,
LPA 170 solvent had degraded by 90 % based on theoretical oxygen (ThO2) consumption.
While LPA 170 solvent met the OECD ‘ready‘ biodegradation requirement of at least 60 %
theoretical oxygen (ThO2) consumption after 28 days, the substance did not reach 60 %
in the ten-day window. However, in the introduction to Section 3 of the OECD testing
guideline, the ten-day window should not be applied to the testing of mixtures such as oils
and surfactants.2 As a result, LPA 170 solvent can be classified as ‘readily biodegradable‘.
Based on these results, it can be expected that other LPA solvents will demonstrate a
similar biodegration profile.
Figure 1:
Biodegradation of Sasol North
America LPA 170 solvent
OECD 301F theoretical
oxygen demand
100
90
LPA 170
80
ThO2 [%]
70
60
50
40
30
20
10
0
0
5
10
15
20
25
30
Days
Transportation Reclassification
Sasol North America recently completed combustibility testing on several products
regulated by DOT as combustible liquids. Due to favourable results, Sasol has reclassified
LPA, LPA 142, LPA 150 and LPA 170 solvents from ‘hazardous‘ in transportation to ‘not
regulated‘ because they are not subject to 49 CFR Subchapter C – Hazardous Material
Regulations (Parts 171 to 180).
For more information, please visit:
www.sasoltechdata.com/tds/combReclass.pdf
Regulatory Compliance
Please contact a sales representative for more information on particular FDA regulations or
for solvent status under CARB or as an LVP-VOC for consumer products.
14
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
4.4 ODC Solvents
Description
Sasol’s ODC drilling fluid base oils are high-purity hydrocarbons in the kerosene boiling
range. Sasol ODC oils are light, colourless, non-fluorescent oils with low viscosity and
mild odour. They have extremely low sulphur and nitrogen content. All Sasol ODC base oils
are well suited to be high-performance, low-toxicity replacements for diesel oil in oilfield
drilling applications.
Physical Properties
Typical Properties
Method
ODC
ODC-15
ASTM D-86
370
374
480
490
Distillation range, °C
IBP
FP
Flash point, (PM) °C
Freeze point, °C
Pour point, °C
Specific gravity, g/ml @ 15 °C
Sulphur, ppm
Colour, Saybolt universal
Viscosity, cSt
20 °C
ASTM D-93
70
62.8
ASTM D-2386
< –32
< –30
ASTM D-97
< –32
< –30
ASTM D-287
0.810
0.821
<1
<1
6.71
ASTM D-156
+30
+30
2.2
2.1
1.6
1.53
API, calc.
0.16
0.2
ASTM D-3539
0.019
0.014
ASTM D-611
70
62
ASTM D-1133
32
36
EPA 8260B
ND*
< 800
EPA Method 1654A
‘MI Modified‘
ND
< 2.5
ASTM D-445
40 °C
Vapor pressure, torr @ 20 °C
Evaporative rate, n-butyl acetate e = 1
Aniline point, °C
KB value
Aromatics – BTEX, ppm
Polycyclic aromatic hydrocarbon (PAH) as
phenanthrene, detection limit 0.0025 mg/g
* Method detection limit 36 ppb
Applications
Sasol’s ODC drilling fluid base oils have been developed for use as base oils in drilling muds,
as water-based mud-additives, as stimulation fluids and as spotting fluids.
Advantages
•
•
•
•
Blending of isoparaffins, napthenics and aromatics
Wide flash point > 60 °C
Low viscosity and mild odour
Non-fluorescent
15
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
4.5 Wellbore Cleaner
Description
Cementing operation is one of the most important links in drilling engineering. Its
main function is to isolate the oil, gas and water in the well, protect the casingof
the oil and gas well, and increase the service life and output of the oil and gas well.
The key point is how to control the cementation strength of cement slurry at the
cement-formation interface and prevent interflow of the formation fluid at the
cement-formation interface.
The wellbore cleaner is applied before cementing when finishing OBM drilling. It is
designed to change the borehole and casing wetting from lipophilicity to hydrophily,
then to clean oil stains and mud cakes on the borehole and to improve the cementation strength between the interface and cement ring.
Applications
The product is applied before cementing when finishing OBM drilling.
Key Benefits
• Excellent cleaning performance at the cement-formation interface
• Ability to effectively remove the fluffy mud cake and oil stains on the borehole,
thereby improving the water wetting ability on the borehole
• Good temperature resistance
• Customisable cleaning formulations available for special customers
Cleaning Ability
Formulation
16
Dosage, wt %
Surfactant
Na2CO3
Tap water
/
/
TERRAVIS
7PS-II
6
3
TERRAVIS
B43
9
1
TERRAVIS
30S10
5 - 10
/
MARLINAT
AK23M
5 - 10
/
First Interface
Second Interface
Sasol Products for Drilling and Completion
Oilfield Chemicals Portfolio
4.6 Defoamer
Description
Sasol offers a variety of defoamers used in drilling and production. The typical TERRAVIS N
RT 201 products and some light alcohols have excellent defoaming performance.
Applications
• Drilling
• Production
Advantages
• Excellent defoaming performance
• Good salinity resistance
Application Performance
DI-Water
Defoaming rate [%]
Figure 1:
Defoaming performance at 0.5 wt %
of defoamer dosage (based on the
stirring method)
5,000 ppm
50,000 ppm
100,000 ppm
100
90
80
70
60
50
40
30
20
10
Figure 2:
Defoaming performance at 0.2 wt %
of defoamer dosage (based on the
standard Q/SH 1500-0054)
Density recovery rate (%)
0
100
90
TERRAVIS
N RT 201
ALFOL 610
Freshwater-based drilling fluid
ISOFOL 12
Organosilicone
Heavy alcoholbased emulsion
Brine-based drilling fluid
80
70
60
50
40
30
20
10
0
TERRAVIS
N RT 201
ALFOL 610
ISOFOL 12
Organosilicone
Heavy alcoholbased emulsion
17
Oilfield Chemicals Portfolio
5. Sasol Products for
Oil Production
18
Sasol Products for Oil Production
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.1 Foamer
Description
Sasol offers a variety of foamers for different salinity requirements. The typical two products TERRAVIS S27S and AK13M have excellent foaming and liquid-carrying performance.
They also have excellent temperature resistance and are mainly used for gas well foam
drainage, well washing and sand flushing in oil and gas fields.
Applications
• Gas well foam drainage
• Well washing and sand flushing
Applied Range
Salinity
Product
0 to 50,000
ppm
50,000 to
100,000 ppm
≥ 100,000
ppm
1 TERRAVIS S07S
++++
++
+
2 TERRAVIS S27S
++++
++++
++
+
++++
++++
3 TERRAVIS AK13M
Characteristic
Good foaming performance at ≤ 50,000 ppm
salinity
Good foaming performance at ≤ 100,000 ppm salinity
Good foaming performance at ≥ 50,000 ppm
salinity
Key Benefits
•
•
•
•
•
•
Excellent foaming and foam stability
Excellentliquid-carrying capacity
Tolerance to brines with different salinity
Good methanol and condensate oil resistance
Good salt resistance
AK13M: especially suitable for making foamer stick due to its very low water content
Foaming and Liquid-Carrying Capacity
TERRAVIS AK13M
800
Graph 1:
Foaming ability
TERRAVIS S07S
600
500
400
300
200
100
DI-water
150 ppm
brine
Method: modified Ross-Miles foam meter
Dosage: 0.175 % am product
Graph 2:
Liquid-carrying capacity (60 °C)
100
700
0
TERRAVIS AK13M
TERRAVIS S27S
Liquid-carrying rate [%]
Initial foaming height [mm]
TERRAVIS S27S
60
40
20
0
30,000 ppm 50,000 ppm 100,000 ppm
brine
brine
brine
Temperature: 70 °C
Brine: NaCl:CaCl2 = 4:1
80
Liquid 1
Liquid 2
Liquid 3
Liquid 4
Liquid 1 Liquid 2 Liquid 3 Liquid 4 Liquid 5 Liquid 6 Liquid 7 Liquid 8
50,000 ppm brine
100,000 ppm brine
DI-water + 15 % condensate oil
50,000 ppm brine
+ 15 % condensate oil
Liquid 5 100,000 ppm brine
+ 15 % condensate oil
Liquid 6 DI-water + 15 % methanol
Liquid 7 50,000 ppm brine + 15 % methanol
Liquid 8 100,000 ppm brine + 15 % methanol
19
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.2 Binder
Description
As a binder for foamer sticks, Sasol’s TERRAVIS 150NT has good hardness and water
solubility performance. Its final foaming and liquid-carrying capacity are not affected when
made into a foamer stick, and it is highly compatible with other foamer stick ingredients.
Key Benefits
•
•
•
•
•
•
Ability to make high content foamer sticks
High melting point (≥ 55 °C), easy to store and transport
Good water solubility
Good compatibility with foamer
Simple processing technology when used to produce the foamer stick
No organochlorine and heavy metal ions
Recommended Ratio for Foamer Stick
Ratio
Hardness
Dissolution Rate, g/min.
TERRAVIS
150NT
TERRAVIS
AK13M
Room
temperature
50 °C
70 °C
7
3
Good
0.132
1.23
6
4
Good
0.156
1.49
Foaming Performance
Initial foaming height [ml]
700
600
AK13M: 150NT = 4:6
AK13M: 150NT = 3:7
468
500
424
410
398
400
300
209
200
180
100
0
DI water
Method: modified Ross-Miles foam meter
Dosage: 0.175 % am AK13M
20
50,000 ppm brine
Temperature: 700 °C
Brine: NaCl:CaCl2 = 4:1
100,000 ppm brine
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
Production Process
Melt it at 70 °C
Mix with AK13M
Allow to cool in the mould
TERRAVIS 150NT
FOAMER STICK
TERRAVIS AK13M
21
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.3 High-Efficiency Concentrated
Acid Solubiliser
Description
Sasol’s acid solubiliser system consists of TERRAVIS 7PS surfactant, ethylene glycol
monobutyl ether and water. It has excellent mutual solubility (intersolubility) and compatibility. It is an effective additive for acidising stimulation that can be dissolved in acid (or
water) and oil.
Key Benefits
•
•
•
•
•
•
•
Ability to improve the flowback rate of the residual acid
Excellent intersolubility with water and oil
Good compatibility in acid solution at 90 °C
Prevention of the emulsification of acid and crude oil
Prevention of the formation of acid slag during acidising
Good synergy with the other additives in the acid solution
Low pour point
Application
Production well acidisation
Figure1:
Intersolubility of acid
solubiliser in 15 % HCl
Commercial
Sasol’s
Commercial
Sasol’s
Figure2:
Compatibility of acid solubiliser
at 90 °C
Recommended Formulation
Table 1:
Formula of acid solubiliser for
reference
Table 2:
Application properties of acid
solubiliser
22
Formula
Components
Items
wt %
TERRAVIS 7PS
20
Ethylene glycol
monobutyl ether
10
Water
70
Appearance at 25 °C
Density at 20 °C,
g/cm3
Compatibility at 90 °C
Index
Clear liquid
0.9930 to 0.9940
No layer, cloud or deposit after
mixing with acid
Mutual solubility
Clear solution, no layer, no
deposit
Closed-cup flash
point, °C
≥ 30
Pour point, °C
≤ -10
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.4 Flowback Agent
Description
Sasol’s flowback agent is a performance-optimised nonionic surfactant with excellent
surface activity. It is mainly used in hydrofracturing in order to improve the displacement of
fracturing fluid during the flowback stage and reduce formation damage.
Key Benefits
• Low surface tension
• Low CMC
• Excellent wettability, especially on hard surfaces such as a ceramic surface, and low
concentration
• Excellent acid resistance
• Excellent salt resistance
• Good synergy
• No fluoride, readily biodegradable
• No solvent, non-flammable
• Non-explosive
Application
• Hydrofracturing
Typical Properties
Typical Properties
17 % G12-7N
17 % 7PT
17 % 7NT
Appearance
Cloudy to clear
Cloudy, layer
Clear
ST @ 3,000 ppm, mN/m
27.69
27.53
28.5
IFT @ 3,000 ppm, mN/m
1.21
3.26
3.16
Pour point, °C
–10 to –5
–10 to –5
–10 to –5
Flash point, °C
> 150
> 150
> 150
Density @ 20 °C, g/cm
3
pH, 1 % in water solution
CMC for 100 % am product, ppm
1.0
1.0
1.0
5 to 7
5 to 7
5 to 7
83
41
73
23
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
[mN/m]
Surface Tension and Interfacial Tension at 25 °C
Surface tension
IFT
50
40
30
27.69
27.53
28.5
20
10
1.21
3.26
3.16
Dosage [500 ppm]
0
G12-7N
7PT
7NT
TERRAVIS 7NT
TERRAVIS 7PT
TERRAVIS G12-7N
1# fluorocarbon
2# fluorocarbon
Dynamic contact angle [°]
Wettability – Dynamic Contact Angle on Ceramic Surface, 25 °C
Ceramic surface, 50 ppm
80
75
70
65
60
55
50
0
5
10
15
20
25
30
Droplet spreading time [S]
24
29
TERRAVIS 7PT
TERRAVIS 7NT
TERRAVIS G12-7N
28
27
26
25
24
4 % am HCI
8 % am HCI 12 % am HCI
Salt Resistance (25 °C)
Surface tension @ 500 ppm
[mN/m]
Surface tension @ 500 ppm
[mN/m]
Acid Resistance (25 °C)
29
28
TERRAVIS 7PT
TERRAVIS 7NT
TERRAVIS G12-7N
27
26
25
24
5,000 ppm 50,000 ppm 100,000 ppm
brine
brine
brine
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.5 Heavy Oil Viscosity Reducer
Description
Sasol’s heavy oil viscosity reducers – TERRAVIS 9PS and 9NT – have good surface activity,
can lower oil well back pressure by effectively reducing crude oil viscosity and assure the
normal production of oil wells. In addition, they have good temperature resistance and hard
water stability. Aqueous solutions form O/W emulsions that greatly reduce the viscosity of
heavy oil and the power required by pumping units.
Key Benefits
•
•
•
•
•
Excellent viscosity reduction behaviour
Low pour point, easy to operate
Excellent emulsification properties and easy to demulsify
Good hard water stability
Good temperature resistance
Application
• Crude oil production
Viscosity Reduction Performance
30,000
Crude oil
Viscosity [mPa·s]
25,000
Mixture of oil and water +0.1 % TERRAVIS 9NT
Mixture of oil and water +0.1 % TERRAVIS 9PS
20,000
15,000
10,000
5,000
0
Low-viscosity oil
Medium-viscosity oil
High-viscosity oil
≤ 1,000 mPa·s
1,000 to 10,000 mPa·s
10,000 to 50,000 mPa·s
Method: Q/SH 0066-2007
Temperature: 50 °C
25
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.6 Paraffin and Asphaltene
Dispersant
Description
Drop in temperature and pressure downhole triggers paraffin / asphaltene precipitation.
Some of Sasol’s surfactants can be used as dispersant to disperse, inhibit or reduce the
pour point of the crude oils thereby preventing or delaying the onset of wax and asphaltene deposition downhole.
Main Performances
•
•
•
•
•
Excellent dispersibility for paraffin and asphaltene
Excellent synergistic effect with solvent
Low pour point, easy to operate
Good hard water stability
Good temperature resistance
Applications
Crude oil production
Dispersibility of Paraffin and Asphaltene
60
Figure 1:
Components of
crude oil
40
Weight (%)
Picture 1:
Appearance of crude oil at room
temperature
Analysis of Heavy Oil From Canadian
41.4
29.4
29.3
Paraffins
Asphaltenes
20
0
Picture 2:
Dispersibility of crude oil before and
after treatment with dispersant
26
Oily constituents
Sasol Products for Oil Production
Oilfield Chemicals Portfolio
5.7 Intermediate Pour Point
Depressants for the Oil Industry
Description
TERRAVIS PI based on Sasol’s long-chain linear alcohols have a strong effect in lowering
the pour point of crude oils by interacting with paraffins in the oil.
Changing or disrupting the wax crystalline structure diminishes the gelling of the oil’s
low-temperature flow properties through the pipeline or during storage as well as assisting
the restart of the pipeline.
Product Portfolio
TERRAVIS PI 110
TERRAVIS PI 120
TERRAVIS PI 130
TERAVIS PI 140
Appearance@20 °C
Liquid, clear to
slightly cloudy
Liquid
Liquid to solid
Solid
Solid content [%wt]
38 – 42
38 – 45
38 – 42
38 – 42
Solvent
Pour point [°C]
Density @20 °C [g/ml]
Viscosity @20 °C [mPa·s]
Average carbon number of
pendant alkyl chains
Xylene
Xylene
Xylene
Xylene
14 max.
12 max.
19 max.
34 max.
0.86 – 0.92
0.86 – 0.92
0.86 – 0.92
0.86 – 0.92 @ 40 °C
150 max.
100 max.
100 max.
100 max. @ 40 °C
20
22
24
29
Applications
Production, storage and transportation of waxy oils
Main Performances
TERRAVIS PI products are highly effective in lowering the pour point by adapting the
pendant alkyl chain length of the comb polymer to the carbon number distribution of the
oil’s paraffin waxes.
27
Oilfield Chemicals Portfolio
Sasol Products for Oil Production
Figure 1:
Pour point reduction of treated model
oils with TERRAVIS PI
Pour point reduction [∆T]
20 °C
500 ppm PPD
Model oil 1 [PP-30 °C]
Model oil 2 [PP-40 °C]
Model oil 3 [PP-60 °C]
15 °C
10 °C
5 °C
0 °C
TERRAVIS PI 110
30 °C
Pour point reduction [∆T]
Figure 2:
Influence of pendant alkyl chain
length on pour point reduction
Model oil 3
500 ppm
1,000 ppm
TERRAVIS PI 130
TERRAVIS PI 140
EVA* PPD
*EVA = Ethylene-Vinyl-Acetate copolymer
2,000 ppm
20 °C
10 °C
0 °C
TERRAVIS PI 110
28
TERRAVIS PI 120
TERRAVIS PI 120
TERRAVIS PI 130
TERRAVIS PI 140
Oilfield Chemicals Portfolio
Sasol Products for Oil Production
By interacting with the paraffin wax crystals, TERRAVIS PI products also control low
temperature viscosities of waxy oils and strength of gelled waxes.
Figure 3:
Interaction of TERRAVIS PI with wax
crystals – viscosity profile
TERRAVIS PI 110
TERRAVIS PI 120
TERRAVIS PI 130
500 ppm PPD
@6s-1
RheoStress 6,000
500
Viscosity [mPas]
TERRAVIS PI 140
400
300
200
100
0
0 °C
Figure 4:
Interaction of TERRAVIS PI with wax
crystals – gel strength @4 °C
5 °C
10 °C
15 °C
20 °C
25 °C
30 °C
35 °C
40 °C
2,800
500 ppm PPD
Model oil 1 [PP-30°C]
Yield point [Pa]
2,400
Model oil 3 [PP-60°C]
2,000
1,600
1,200
800
400
0
Untreated
TERRAVIS PI 110 TERRAVIS PI 120 TERRAVIS PI 130 TERRAVIS PI 140
29
Oilfield Chemicals Portfolio
Sasol Products for Oil Production
5.8 Easier-to-Handle
Intermediate Pour Point
Depressants
Description
TERRAVIS PI products based on Sasol’s long-chain linear and heavy Guerbet alcohols
reduce the pour point of a liquid 40 % active PPD polymer solution below 0 °C or turn a
solid product into a liquid product at ambient temperature.
Product Portfolio
TERRAVIS PI 110
TERRAVIS PI 111*
TERRAVIS PI 140
TERAVIS PI 141*
Appearance@20 °C
Liquid, clear to
slightly cloudy
Liquid
Solid
Liquid
Solid content [%wt]
38 – 42
39.1
38 – 42
39.5
Xylene
Xylene
Xylene
Xylene
0.86 – 0.92
0.89
0.86 – 0.92
@ 40 °C
0.89
150 max.
37
100 max. @ 40 °C
65
20
20
29
29
-
32
-
32
Solvent
Density @20 °C [g/ml]
Viscosity @20 °C [mPa·s]
Average carbon number of pendant alkyl chains
Linear
Branched
* developmental products
30°C
Pour Point
24°C
20°C
17°C
12°C
10°C
0°C
-2°C
-10°C
30
40 % active polymeric PPD solution
TERRAVIS PI 110
TERRAVIS PI 111
TERRAVIS PI 140
TERRAVIS PI 141
Oilfield Chemicals Portfolio
Sasol Products for Oil Production
Applications
Production, storage and transportation of waxy oils
Main Performances
TERRAVIS PI products are highly effective in lowering the pour point by adapting the pendant
alkyl chain length of the comb polymer to the carbon number distribution of the oil’s paraffin waxes. Adding Guerbet structures to the polymer system reduces further the pour point
when the ratio of average carbon numbers of pendant linear to Guerbet alkyl chains matches
optimal with the paraffin waxes of the treated oil.
Figure 1:
Model oils, high-paraffinic and
water-free
10
Pour point
Wax content
9
8
Model oil 1 Model oil 2 Model oil 3
30 °C
40 °C
60 °C
14 %
14 %
14 %
Solvent: n-decane
7
Model oil 1
Model oil 2
Model oil 3
6
5
4
3
2
1
0
C16 C19 C22 C25 C28 C31 C34 C37 C40 C43 C46 C49 C52 C55 C58 C61 C64 C67 C70
Carbon number
20 °C
Pour point reduction [∆T]
Figure 2:
Pour point reduction of treated
model oils with TERRAVIS PI
ASTM D5985
Model oil 1 [PP-30°C]
Model oil 2 [PP-40°C]
Model oil 3 [PP-60°C]
15 °C
10 °C
5 °C
0 °C
TERRAVIS PI 110
TERRAVIS PI 111
TERRAVIS PI 140
TERRAVIS PI 141
31
Oilfield Chemicals Portfolio
Sasol’s Cleaning Products
6. Sasol’s Cleaning Products
32
Sasol’s Cleaning Products
Oilfield Chemicals Portfolio
6.1 Sludge and Drilling Cutting
Cleaner
Description
Drilling cuttings from oil base mud and sludges are a kind of oil-bearing solid waste formed
during a variety of processes such as oil exploration, transportation, refining and wastewater treatment. Oil industry operators around the world face increased challenges when
it comes to dealing with them as a result of the more stringent requirements imposed by
regulatory agencies. Government entities such as the US Environmental Protection Agency
(EPA) and Norway’s State Pollution Control Authority (SFT) set strict limits regarding retention on cuttings (ROC) for drilling cuttings and sludges.
Sasol has accumulated a great deal of experience in soil remediation and cleaning drilling
cutting, having used surfactants based on our broad range of chemical raw materials since
1980. Now we can customise cleaning formulations in combination with separation and
thermal washing technology to reduce ROC for the different sludge and drilling cuttings.
Benefits of Chemical Cleaning
•
•
•
•
Excellent cleaning ability
Simple and convenient technological process
No limitations regarding temperature
Energy consumption and processing cost are low relatively
Application
• Oil-bearing solid waste cleaning, such as drilling cuttings, sludge and oil sand
How We Help You Select the Right Product for Your Field
1) We can customise the cleaner formulation for each customer.
• Sasol’s cleaning products are mainly derived from more than hundreds of various
types of surfactants.
• Sasol’s lab virtual screening is based on the different type of solid waste and treatment processes provided by the customer.
2) We canoptimise and provide the best cleaning solution in combination with the field
treatment processes, including cleaning dosage, temperature and water treatment
suggestion.
3) Screening principle:
• Reduce the interfacial tension of oil and sludges or drilling cuttings, to facilitate the
separation of solid and oil
• Facilitate the separation of oil and water, avoid emulsification
• Good wetting and penetration ability
• Good efficiency of water resource reuse
33
Sasol’s Cleaning Products
Oilfield Chemicals Portfolio
ROC Test Method – Sasol Utilises the Retort Distillation Method
ROC test method
Main instrument
1
Extraction
Soxhlet extractor
2
Retort distillation
Retort kit
3
Defect
Long test time, can cause environmental pollution when solvent is
used, inconvenient operation and handling in the field.
The accuracy is not very good when ROC is less than 1 %.
Gas chromatography Gas chromatograph
Long test time, complicated operation and inconvenient operation
and handling in the field.
It will lead to high test results, as other inorganic and organic components are burned at the same time.
4
Burning
Muffle
5
Spectrophotometry
Spectrophotometer
Long test time, complicated operation and inconvenient operation
and handling in the field.
Case
Before and after cleaning
Customer
A
Target
Technical requirements
ROC, %
original
ROC, %
after cleaning
Cleaning
temp. °C
Aged sludge
ROC < 2 %
11.2
1.67
50
B
Aged sludge
ROC < 2 %
6 to 8
1.6
Room temp.
C
Oil-bearing filter material
ROC ≤ 0.3 %
0.9
0.3
Room temp.
D
Aged sludge
ROC < 3 %
6.86
1.2
Room temp.
Appearance of the Sludge Before and After Cleaning
Untreated and treated sludge of domestic field A
Untreated and treated sludge of domestic field B
34
Oilfield Chemicals Portfolio
Sasol Products for Enhanced Oil Recovery
7. Sasol Products for
Enhanced Oil Recovery
35
Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
7.1 ALFOTERRA and SOLOTERRA –
Surfactants for ChemicalEnhanced Oil Recovery
Developing a field-specific chemical formulation is process-dependent. Sasol offers two lines
of surfactants for various types of chemical EOR. We select and design our products to match
the specific conditions of your oil reservoir, taking into account reservoir temperatures, the
salinity of injection and formation waters, rock type and the nature of the crude oil.
Chemical Flooding – How Sasol Surfactants Work
Sasol surfactants are well suited for usage in a variety of surfactant-based chemical
flooding technologies. Whether the application is for a surfactant-enhanced water flood,
surfactant-polymer technology or alkaline-surfactant-polymer technology, Sasol has
the broadest range of hydrophobes available to tailor the surfactant around the specific
reservoir parameters using actual reservoir fluids. Sasol surfactants are applicable to these
conditions:
•
•
•
•
•
•
Figure 1, left:
Reduction of capillary pressure
Low to high temperature Low to high salinity Reduction of capillary pressure
High efficiency – use level of 0.1–0.5 %
Ultra-low IFT achieved with and without alkali
High concentration products (85 to 100 % active)
Reduction of Capillary Pressure
and Interfacial Tension
Oil Solubilisation Variation (SP*)
Due to Surfactant Structure
Left: Alkali/ALFOTERRA/polymer
Right: Polymer/brine
Left: ALFOTERRA 123-8S 90
Right: ALFOTERRA 145-8S 90
Figure 2, right:
Oil solubilisation variation (SP*)
due to structure
Sasol’s Testing Procedures
How We Help You Select the Right Product for Your Field
•
•
•
•
•
•
•
36
Phase behaviour studies with field oil and field brine or synthetic oil and brine
Solubility studies
Rock adsorption
Thermal stability
Tailored chemical design based on broad in-house hydrophobe portfolio
IFT measurement
Polymer compatibility
Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
Sasol Provides Experienced Technical Solutions and Services
Sasol Performance Chemicals has a network of seven R & D facilities in five countries (USA,
China, Italy, Germany, South Africa) offering product development and screening facilities.
Sasol R & D offers EOR screenings such as phase behaviour, spinning drop interfacial tension (Figure 3) and static pack studies. This enables us to recommend the right surfactant
choices out of our portfolio to speed up your evaluation process. In addition, pilot facilities
mirroring all our major production processes allow development and upscaling of custommade products.
Figure 3:
Minimum dynamic IFT between heavy
crude oil and brine in an ALFOTERRA
surfactant ASP formulation
Minimum Dynamic IFT between Heavy Crude Oil and Brine
in an ALFOTERRA Surfactant ASP Formulation
1
0.1
ASP Formulation
0.2 wt % ALFOTERRA surfactant,
1,000 mg/L polymer and various
alkali concentrations dissolved in
softened injection
NaOH
Na2CO3
0.01
0.001
0.0001
1E-05
0
0.35
0.5
0.75
1
1.25
1.5
1.75
Sasol’s surfactant portfolio for chemical EOR covers a broad range of reservoir conditions.
SOLOTERRA AAS surfactants are designed for variable-temperature and low-salinity
reservoirs. SOLOTERRA ECA surfactants work well in high-temperature and high-salinity
reservoirs, while the ALFOTERRA surfactant group performs best in lower-temperature
reservoirs and within a broad range of salinity. (Figure 4)
SOLOTERRA AAS
(alkyl aryl sulphonates)
Sasol EOR Surfactant Portfolio
Temperature
Figure 4:
Sasol EOR surfactant portfolio
s
ECA a nt
a
a
f
r ct
co-su AS
for A
S
(eth OLOT
er c ERR
A
arb
oxy ECA
lic a
cid
s)
ALFOTERRA
Salinity
37
Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
7.2 ALFOTERRA – Surfactants for
Mooney Field ASP Flooding
The Mooney Field, operated by BlackPearl, is a conventional heavy oil property located in
north-central Alberta, Canada. The field was initially developed for conventional production using horizontal wells. A water flood was attempted in 2006; however, it only
recovered an additional 2 % to 3 % of the OOIP. BlackPearl believed the performance of
the Mooney Field could be further enhanced through ASP flooding. A three-well polymer
pilot project was initiated in 2008 and operated for approximately 14 months, resulting
in an oil recovery increase of approximately 18 % OOIP. Based on these results, BlackPearl
believed the performance of the Mooney Field could be further enhanced through ASP
flooding.
Reservoir
Bluesky SS
Depth, m
875 to 925
Net pay, m
3 to 5
API, °
12 to 19
Viscosity, cp
150 to ~2,000
Permeability, md
1,500
Temperature, °C
29
Initial water saturation, %
35
Initial reservoir pressure, kPa
17.6
Oil formation volume factor, m³/m³
1.052
Total dissolved solids
20,300 to 28,700
Na2CO3 (1.25 %)
Alcohol propoxy sulphate (0.15 %)
Associative polymer (2,200 mg/L)
80
70
Laboratory Core Flood Data
Independent third-party test work for BlackPearl
determined that alkaline surfactant polymer (ASP)
flood technology a Sasol Performance Chemicals’
ALFOTERRA surfactant at 1,500 ppm performed the
best, out of 68 surfactants tested.
This product was combined with 1,250 ppm sodium
carbonate and an associative polymer at 2,200 ppm
based on the injection water chemistry.
Third-party sand pack analysis revealed a tertiary oil
recovery potential of 32 % Soi (51.2 % Sor), affording
a total recovery of 69 % Soi.
60
50
40
30
Water flood
Chemical flood
20
ASP
10
AP
SP
ASP
0
ASP
0
0.25
0.5
0.75
1
1.25
1.5
1.75
Normalised cumulative produced fluids (PV/PV water flood)
38
The Mooney Field was discovered in 1986. The productive part of the field covers approximately 57,920
acres or 90 sections.
BlackPearl is the operator and holds 100 % interest. The geology of the Bluesky formation at at the
Mooney Field is shallow marine, relatively clean and
continuous shoreface sand.
5,800
Initial solution gas oil ratio, m³/m³
Cumulative oil recovery (total % OOIP/water flood% OOIP)
Field Data
Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
Field Results
A field pilot with the selected ASP formulation was injected in the form of 0.35 pore
volume (PV) of ASP, followed by 0.4 PV of polymer, followed by chase water. ASP flood
implementation commenced with Phase 1 injection beginning in September 2011.
Using incremental production results from Phase 1 wells, independentanalysis done by
Canaccord Genuity estimates an incremental 18 % oil recovery rate due to the ASP flood.
Phase 3
Phase 2
Phase 1
T73
T72
T71
1 mile
R10
R9
R8
R7W5
Future
development
Company lands
Company wells
Area wells
Development of Phase 2 and Phase 3 lands at the Mooney Field is planned, with ASP injection scheduled to last several more years, in order to reach the overall target-injected PV.
References
BlackPearl (2014), http://www.blackpearlresources.ca/s/Mooney.asp
Canaccord Genuity (2012), https://research.canaccordgenuity.com/_layouts/researchnoteviewer. spx?pubid=73514
SPE 169154-MS (2014), https://www.onepetro.org/conference-paper/SPE-169154-MS
39
Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
7.3 Surfactants for ThermalEnhanced Oil Recovery
Enhanced Crude Oil Production from Steam Operation
Sasol offers a line of surfactants specifically formulated to address the challenges of
heavy oil and bitumen recovery in high-temperature applications. These products are
ideally single surfactants but may also consist of one or more co-surfactants, assuring
that each formulation is designed to meet the specific conditions of your reservoir.
Sasol’s high-temperature surfactants can be used in applications such as:
• SAGD (Steam-assisted gravity drainage)
• Steam flooding
• CSS (Cyclic steam stimulation)
• Thermal steam foam flooding
• High-temperature surfactant flooding
Surfactants for Thermal Applications
To address the needs of enhancing oil recovery in thermal applications, Sasol has developed the SOLOTERRA series product line. SOLOTERRA surfactants exhibit the following
properties:
•
•
•
•
•
High-temperature stability, up to 250 ºC
Excellent brine stability
Low interfacial tension
High oil solubilisation (SP*)
Stable foam formation
The SOLOTERRA surfactant product line is composed of alkyl aryl sulphonates, alcohol
ether carboxylates and solvents.
Surfactants can improve steam floods or SAGD by lowering the interfacial tension of the
oil, by forming lower viscosity oil emulsions or by altering the wettability of the rock.
Surfactants can also disperse asphaltenes or paraffins.
Surfactants may be added to steam or gas processes to generate foam for mobility
control, improving vertical or horizontal sweep efficiency.
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Oilfield Chemicals Portfolio
Sasol Products for Enhanced Oil Recovery
Surfactants for Steam Foam Applications
Sasol’s SOLOTERRA surfactants are formulated to generate stable foam under steam
conditions. SOLOTERRA surfactants can generate foam for steam mobility control, helping
reduce steam override, improve conformance to alternate flow paths and improve sweep
efficiency while remaining stable.
Testing of bitumen with a viscosity of 915,000 cP at 20 °C (6.1 cP at 200 °C) and density
929 kg/m3 (20.8 oAPI) in an Ottawa sand-packed column showed that both SOLOTERRA
922 and SOLOTERRA 923 surfactant foams were excellent candidates for additional
testing.
Both surfactants show increases in the apparent viscosity of steam by three orders of
magnitude without the presence of bitumen. In the presence of bitumen, the apparent
viscosity of steam is still increased by two orders of magnitude by the surfactant foam.
(A) SOLOTERRA 922
(B) SOLOTERRA 922
No bitumen
With bitumen
No surfactant
1,000
Steam apparent viscosity [cP]
Steam apparent viscosity [cP]
Figure 1:
Steam apparent viscosity at 250 °C
in sand-packed columns with and
without the presence of bitumen due
to generation of stable foam using (A)
SOLOTERRA 922 surfactant and (B)
SOLOTERRA 923 surfactant
100
10
1
0.1
0.01
0.001 0
2
4
6
Injected liquid PV
8
10
No bitumen
With bitumen
No surfactant
1,000
100
10
1
0.1
0.01
0.001 0
2
4
6
8
10
Injected liquid PV
Key Results from Steam Foam Laboratory Test at 250 °C
• High-temperature stability, up to 250 °C
• Stable foam formation
• Increase apparent steam viscosity by two to three orders of magnitude in the presence
of bitumen
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Oilfield Chemicals Portfolio
Sasol Products for Enhanced Oil Recovery
7.4 Sasol‘s Additives Improve
CO2 Floods
Sasol has developed a range of miscibility-enhancing additives for CO2 enhanced oil
recovery (EOR). Incorporating these additives with CO2 injection improves the interaction
between injection gas and crude oil, leading to increased miscibility and lower injection pressure. The benefits are twofold. First, it provides new opportunities to shallow
reservoirs that were not previously candidates for CO2 miscible flood applications due to
miscibility pressures that were above the formation parting pressure. Second, reservoirs
that are currently at near-miscible conditions could see further enhanced recovery as a
result of the improved miscibility.
Influence of Sasol’s Additives on the CO2 Flooding Process Due to Reduction
of the Miscibility Gap
Additive
Additive
Additive
2 wt %
CO2
CO2
cp
cp
cp
C7+
2
2
2
4 wt %
2 wt %
CO2
C7+
Immiscible
C7+
FCM
MCM
C1–6
C1–6
C1–6
The diagrams above illustrate how Sasol additives significantly reduce the region of immiscibility at constant pressure. This enables an immiscible flood to evolve into a multiplecontact miscible (MCM) or even first-contact miscible (FCM) type condition. Ultimately,
production is enhanced, costs reduced and project economics improved.
Miscibility Gap of an Asian
Crude Oil and CO2 @ 65 °C
Swelling Behavior of an Asian
Crude Oil and CO2 @ 65 °C
6,000
1.6
cp
2
3,000
2,000
1,000
0
0
pure CO2
+2 wt % ME-5
+2 wt % ME-6
1.4
Swelling factor, SF
Pressure [psi]
5,000
4,000
pure CO2
+2 wt % ME-5
+2 wt % ME-6
1
1.2
1.0
0.8
0.6
0.4
0.2
20
40
60
80
Crude oil, [wt %]
100
0.0
0
1000 2000 3000 4000 5000
Pressure [psi]
Due to the improved miscibility behavior by incorporating Sasol’s additives into the
injection gas, lower pressures are required for full miscibility. The extent of the region of
immiscibility is also reduced significantly.
Additionally, the swelling factor (SF) increases due to improved condensation of the injection gas into the residual crude oil. SF of the Asian crude oil is about 20 % higher with the
additives compared to pure CO2.
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Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
Improvement of the Swelling Behavior
Pure CO2
+2 wt % ME-5
+2 wt % ME-5
32 %
38.5 %
39 %
Enhancing miscibility of crude oil residual saturation will improve the recovery rate through
viscosity reduction and oil swelling effects. The result is a higher recovery factor, as oil in
previously inaccessible pore space is displaced from the reservoir rock. Reduction in crude
oil viscosity is a further benefit that also leads to an improved liberated oil mobility ratio
within the reservoir.
Sasol’s novel additives can make miscible CO2 injection an economic oil recovery technique
for shallow or fractured reservoirs, which would otherwise produce oil with marginal
economics.
Reduction of the Miscibility Pressure for an Asian Crude Oil
and CO2 @ 65 °C Due to Incorporation of Sasol’s Additives
Pressure
Pure
CO2
4750 psi
2 wt %
ME-6
3980
psi
2 wt %
ME-5
2030 psi
2610 psi
3190 psi
3770 psi
4100 psi
In the phase behavior photographs above, the physical minimum miscibility pressure
(MMPP) required for FCM flooding is reduced significantly from 4750 psi with CO2 alone to
3980 psi and 4100 psi respectively, with the addition of 2 wt % of two different additives.
Physical Properties of the Additives
Sasol’s additives are easily dissolved and co-injected with supercritical CO2, demonstrating
good performance at low dosage. The additives are supplied as high active products
(> 95 %) to streamline logistics, while the low viscosities (< 30 mPa·s @ 40 °C) and pour
points (< –10 °C) enable easy handling. The additives are also safe for operations, with
high flash points of > 65 °C.
Physical Properties of Sasol’s Additives
Property
Pour point
Viscosity @ 40 °C
Value
< -10 °C
< 30 mPa·s
Flash point
> 65 °C
Activity
> 95 %
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Oilfield Chemicals Portfolio
Sasol Products for Enhanced Oil Recovery
Theoretical Background
Interaction of Injection Gas with Crude Oil
The miscibility between injected CO2 gas and crude oil at reservoir conditions is the single
most important parameter in the design of a successful miscible gas flood. The recovery
factors for a CO2 EOR project strongly depend on the interaction of the injected CO2 with
the residual hydrocarbon in the formation. A broad region of immiscibility (miscibility
gap) often exists, which creates phase separation and reduces the displacement efficiency
causing a CO2 flood to be less economical. There are three major processes in CO2 floods:
First Contact Miscibility (FCM):
Optimum recovery rates are achieved when the process is in the first-contact miscible
(FCM) state. In this stage, crude oil and CO2 are miscible at all ratios and form an instant
homogeneous single phase.
Multiple Contact Miscibility (MCM):
More commonly, the injection pathway crosses the miscibility gap where separation and
remixing happens during the flood and the two phases have variable miscibility. When
injected CO2 and crude oil come into contact, vaporization and condensation processes
occur. Both processes lead to a modification of the two coexisting phases. Due to continuous condensation and vaporization over several steps, both phases become more and
more equal until they are identical in composition, resulting in a homogeneous, fully mixed
phase. CO2 flooding in MCM state still provides increased oil recovery, even though efficiency is reduced compared to FCM processes.
Immiscibility:
If the CO2 injection pathway never leaves the miscibility gap, crude oil and injected CO2 will
not become fully miscible during the flood and the process basically remains immiscible.
Incremental crude oil recovery is therefore not enhanced and causes most projects to
become economically infeasible.
Principles of the Different Flooding Processes
FCM
MCM
Immiscible
CO2
CO2
CO2
2
cp
cp
1
C7+ Crude oil
cp
1
C1–6 C7+ Crude oil
1
C1–6
C7+ Crude oil
C1–6
The interaction of CO2 and crude oil, in combination with the flooding scheme, strongly
depends on the injection pressure.
If the gas injection pressure is below the minimum miscibility pressure (MMP), the process
remains immiscible.
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Sasol Products for Enhanced Oil Recovery
Oilfield Chemicals Portfolio
Pressure
Schematic View of the Miscibility Gap
of a Crude Oil with CO2
MMPP
Formation
parting
pressure
cp
MMP
1
2
Reservoir
pressure
Ratio of CO2 to crude
As pressure in the reservoir increases, the miscibility gap becomes
smaller and eventually reaches the MMP, where the flooding
scheme converts from immiscible into an MCM state. From a
thermodynamic point of view, the MMP strongly correlates with
the critical point (cp) of the miscibility gap. The two distinct phases
can only reach full miscibility if those phases become equal in
composition, which is the case at the critical point. The interfacial
tension (IFT) between the two fluids vanishes at cp when full
miscibility is achieved. The physical minimum miscibility pressure
(MMPP) is the lowest pressure required for obtaining instantaneous full miscibility at any ratio. When the CO2 injection pathway
bypasses the miscibility gap, phase separation no longer occurs
and FCM is achieved. This is the most efficient CO2 EOR flooding
process.
As the illustration left suggests, the applicable pressure window
for injection has two limitations. The lower border is the reservoir
pressure itself, while the upper limit is the formation parting pressure. Having an MMP below or as close as possible to the reservoir
pressure is most desirable.
Swelling and Extraction of the Crude Oil
Especially in MCM processes, the interaction between residual crude oil and the
injected gas is crucial for successful recovery. As CO2 condenses into the liquid
oil, the oil phase begins to swell. The increased volume of the swollen oil phase
causes residual oil saturation to be forced out of tight pores of the formation
rock, where it had previously been trapped. At the same time, the viscosity of the
oil is also reduced, improving flow capability through the reservoir even in zones
of low permeability. A second process involves some vaporization of the crude
oil – initially its lighter components, but in time also the heavier ones – into the
CO2 phase. The oil excess phase is enriched with CO2, while at the same time oil
components are dissolved in the CO2 excess phase. Improving the interaction
between CO2 and crude oil increases the sweep efficiency potential. This, along
with a vanishing IFT as miscibility increases, allows for easy mobilization of the
miscible phase through the reservoir.
Don’t miss our SPE papers:
• SPE-181304-MS (presented at ATCE 2016, Dubai)
• SPE-183389-MS (presented at ADIPEC 2016, Abu Dhabi)
• SPE-190288-MS (presented at SPE IOR 2018, Tulsa)
45
Our Global Footprint
Oilfield Chemicals Portfolio
Our Global Footprint
Sasol Performance Chemicals headquarters
Sasol Performance Chemicals locations, including sales offices and laboratories
Xiamen
Taipei
Sasol has large-scale manufacturing capabilities around
the globe
Sasol’s integrated supply chain reliably delivers products of any
quantity, from lab samples to full field shipments
46
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Disclaimer
Source reference
Cover: Dreamstime/Chad Anderson, p. 2: Sasol Performance Chemicals, p.4: Dreamstime/Christopher
Tompkins (left); Dreamstime Christopher Tompkins (right), p. 6: Dreamstime/Pablo Eder, p. 7: Sasol
Performance Chemicals, p. 8: Dreamstime/Alexey Zaytev, p. 13: Dreamstime/Christopher Tompkins,
p. 16, 18, 21, 22, 26: Sasol Performance Chemicals, p. 28: Dreamstime/Vitmark, p. 32, 34: Sasol
Performance Chemicals, p. 35: Fotolia/ping han, p. 36: Sasol Performance Chemicals, p. 39: Fotolia/
Chepko Danil, p. 40: Dreamstime/Sss615 (left); Dreamstime/Fireflyphoto (right), p. 41, 43, 46, 47:
Sasol Performance Chemicals
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property of the Sasol Group of companies, except where it is clear from the context that not. Users
of this document are not permitted to use these trademarks without the prior written consent of
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Disclaimer: The information contained in this document is based on Sasol’s knowledge and experience
at the time of its creation. We reserve the right to make any changes to this document or the products
described therein, as a result of technological progress or developments. This information implies no
liability or other legal responsibility on our part, including with regard to existing third-party patent
rights. In particular, no guarantee or warranty of properties in the legal sense is implied. The customer
is not exempted from the obligation to conduct careful inspection and testing of incoming products.
All our business transactions are governed exclusively by our General Business Terms
(https://www.sasolgermany.de/de/agb/).
47
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Organics Division
Sasol (China) Chemical Co., Ltd.
68 Fang Shui Road
Chemical Industry Park Nanjing
P.R.China 210047
For further information on these or other Sasol products,
please contact a sales representative at:
Qi Hu Marketing Developer
Telephone: +86 (0) 25-5633 5591
Mobile: +86 (0) 180 5205 2858
Qi.Hu@cn.sasol.com
For technical inquiries or product samples, please contact:
www.sasol.com
Oilfield Chemicals Portfolio 04/20
Zhubing Tan Technical Support Engineer
Telephone: +86 (0) 25-5633 5667
Mobile: +86 (0) 180 5205 0606
Zhubing.Tan@cn.sasol.com