CHEMICAL EOR
FIELD EXPERIENCE
Oil Chem Technologies, Inc.
Sugar Land, TX USA
www.oil-chem.com
PRESENTATION OUTLINE
 Introduction to Oil Chem
 EOR – past
 EOR - Oil Chem Technologies
field experience to share
 EOR - future
PRESENTATION OUTLINE
 Introduction
 EOR – past
 EOR - Oil Chem Technologies
field experience to share
 EOR - future
WHY EOR?
Oil Recovery Overview
PRIMARY
15%
RESIDUAL
OIP
33%
WATER
18%
TERTIARY
34%
BAVIER; BASIC CONCEPTS OF EOR PROCESSES(1991)
WHY CHEMICAL EOR?
ECONOMICS FOR FIELD ASP
PROJECTS
Field
W. Kiehl
Cambridge
Daqing
Surfactant
0.10%
0.10%
0.30%
Alkali
0.80%
1.25%
1.00%
Polymer
1050 ppm
1425 ppm
1200 ppm
Tot. Cost
$375,000
$2,518,000
$1,009,000
Inc. ASP Oil
275,000
1,143,000
270,000
Cost/bbl
$1.46
$2.20
$3.79
ROLE OF SURFACTANTS
 Reduce interfacial tension
 Wettability alteration
 Polymer, CDG, BW, etc. can be used
along with surfactants when
mobility control is necessary
SURFACE OR INTERFACIAL
TENSIONS
SYSTEM
mN/m
Water
72
Pure Hydrocarbons
~ 40
Crude Oil
~ 30 - 40
Crude Oil/Water
~ 3 - 30
Crude Oil/Water/Surfactant
< 0.01
RELATIONSHIP BETWEEN CAPILLARY
NUMBER AND OIL RECOVERY
% Oil Recovered
100
80
60
40
20
Nc =  µ / cosθ
Nc = Capillary Number
 = Darcy Velocity
µ = Viscosity
=
Interfacial Tension
Θ=wetting angle
0
1.E-06
1.E-05
1.E-04
Capillary Number
1.E-03
1.E-02
PRESENTATION OUTLINE
 Introduction
 EOR – past
 EOR - Oil Chem Technologies
field experience to share
 EOR - future
LOUDON FLOOD - EXXON
1983
 2.3% surfactant
 96% of the connate salinity
 0.3% pore volume
 0.1% Xanthan gum
 56 million pounds surfactant was
injected in 9 months
 68% ROIP
ROBINSON – MARATHON
1983
 10% surfactant – petroleum sulfonate
 0.8% hexanol as co-surfactant
 2.5% salt
 No polymer
 0.1 pore volume
 19 –21% ROIP
CHEMICAL EOR PAST PROBLEMS
Technical success but limited
“commercial” success Reasons?
EOR BY CHEMICAL FLOOD
Limited commercial success for the
past two decades - Reasons?
 Sensitivity to oil price
 Limitations of chemicals
 High surfactant concentration
 Salinity optimization required
 Potential emulsion block
However,
 Extensive lab evaluations and field pilot tests


support the feasibility of chemical flooding
New chemicals and processes open the door
for new opportunities
Recent field data using these new chemical
and processes proves chemical flooding is
an effective way to recover residual oil
PRESENTATION OUTLINE
 Introduction
 EOR – past
 EOR - Oil Chem Technologies
field experience to share
 EOR - future
CURRENT PROJECTS
 21 Current projects
 20MT to 400 MT Surfactant/mo
 400 MT @ 0.1% = 28,000,000 bbl/mo
injection
 California 50,000 MT surfactant/yr @
0.2% =155,000,000 bbl/yr
 Build plant onsite
CHINA EOR PROJECTS
•
Heavy crude recovery
• Low perm formation oil recovery
• High temp. / high salinities
• Effective, economical offshore EOR
CHINA EOR PROJECTS
INJECTED, ON-GOING & APPROVED PROJECTS
SS B2080, SS B5050, SS B1688,
ORS-46L, ORS-97HF, ORS-41HF
1992-94: LAB EVALUATION
Over 100 Surfactants Were Tested
Including:
 ORS-41
 Petroleum Sulfonates
 Carboxylates
 Lignin Sulfonate/Petroleum Sulfonates
 Microbiological
1995 - INITIAL FIELD
EVALUATION

Daqing No.4 Field - Oil Chem
Technologies’ ORS-41
 Daqing No.1 Field – another US
company’s Petroleum Sulfonate
1996-1998: ENLARGED FIELD
EVALUATION
ORS-41 was the ONLY surfactant
chosen for enlarged field evaluation.
More than 7000 MT of the ORS-41
was injected in several field blocks
and this confirmed the viability of
the ASP process
SPE 36748, 57288, 71061, 71491, 71492
Oil Recovery
Tons/Day
ASP PROJECT USING ORS-41TM
IN DAQING, CHINA
20
15
BEFORE ASP
AFTER ASP
10
5
0
1
2
3
Well Number
4
SPE 36748 (1996)
DAQING CENTRAL WELL
SPE 57288
DAQING CENTRAL FIELD
SPE 84896
HEAVY OIL RECOVERY
BY CREATING WATER
EXTERNAL PSEUDOEMULSION
HEAVY OIL PSEUDO-EMULSION
Control
0.1% SF-100
Surfactant
HEAVY OIL PSEUDO-EMULSION
Control
0.1% SF-100
Surfactant
HEAVY OIL PSEUDO-EMULSION
Control
Oil Viscosity =
6,700 cps
0.1% SF-100
Surfactant
Oil Viscosity <
200 cps
LAB CORE FLOOD DATA
100
90
80
采出程度,%
%
Oil Recovery,
70
60
水驱
试剂1驱(0.1%)
试剂2驱(0.1%)
试剂3驱(0.1%)
50
40
Water flood
30
20
10
0
0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2 2.2 2.4 2.6 2.8 3
Injection
Volume, PV
注入量(PV)
LOW PERM INJECTIVITY
ENHANCER
 Permeability: 0.1 – 10 md
 High water injection pressure makes
water flood unfeasible
 FI series surfactants reduced
injection pressure, increased
injectivity
 Effectively increased the injectivity
in several fields in China and USA
CANADA EOR PROJECTS
•
•
•
•
•
•
HEAVY CRUDE
TAR SAND
LOWER RESERVOIR TEMPERATURES
FRESH WATER SOURCES
HIGH SALINITY RESERVOIRS
FRACTURED CARBONATE FORMATIONS
CANADA EOR PROJECTS
INJECTED, ON-GOING & APPROVED PROJECTS
SS B2080, SS B5050, SS B1688,
ORS-46L, ORS-97HF, ORS-41HF
Some field results will be published
upon completion of projects
NORTHERN CANADA SP
PROJECT
 Heavy oil field, API = 12 -13
 Under polymer flood
 Added 0.1% surfactant with polymer
in November, 2006
 ~ 3 months later, the water cut
reduced from 97% to 58%
UNITED STATES EOR PROJECTS
•
FRESH WATER SOURCES
•
HIGH SALINITY RESERVOIRS
•
FRACTURED CARBONATE FORMATIONS
•
LOW PERMEABILITY
UNITED STATES EOR PROJECTS
INJECTED, ON-GOING & APPROVED PROJECTS
ORS-41HF (2), ORS-62, ORS-97, ORS-46HF,
ORS-162, SS-7593, SS B1688(2)
SHO-VEL-TUM FIELD
 On production > 40 yrs, extensive water flood,


produced 4 bbl/day
ASP started on 2/98, using Na2CO3 and ORS62
Total incremental oil > 10,444 bbl (22 bbls/day)
in 1.3 years
SPE 84904
OIL SATURATION AFTER ASP
INJECTION
35
So, %PV
30
25
20
15
10
5
0.00
0.10
0.20
0.30
0.40
(SURFACTANT CONC, % )(ASP SLUG SIZE)
SPE 84904
MELLOTT RANCH WYOMING
ASP PROJECT
 0.1% ORS-46HF, 1% NaOH, 1300 PPM
polymer
 Recovered 989,000 bbl or 16.4 %
OOIP between 2003 and 2005
 Injection volume decreased 2,800,000
bbl due decreased water cut
MELLOTT RANCH ASP
PROJECT - ORS-46HF
250
180
160
200
OIL, BBL x 1,000
120
150
100
80
100
60
40
50
NEW WELL
WATER FLOOD SINCE 1966
ASP
0
20
0
90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05
YEAR
WATER, BBL x 10,000
140
BIG SINKING, KENTUCKY
Project Information
 Crude oil : 100 Million bbl
 Bottom Hole Temperature: 30oC
 Depth: 1150 ft
 Thickness: 25 feet (7.32 meter)
 Permeability: 45 mD
SPE 100004
BIG SINKING, KENTUCKY
Chemical injected:
0.8% NaOH + 0.1% ORS-162HF
Problems overcome:
 IFT lowered from 23.6 to 0.001 mN/m
 Poor water injectivity
 High water cuts
 220% increase in injectivity
 Large field trial scheduled to begin in
12/2007
SPE 89384
BIG SINKING, KENTUCKY
SPE 89384
TANNER FIELD, WYOMING
Project Information
 Crude oil : 21o API
 Bottom Hole Temperature: 175oF
 Depth: 8915 ft
 Thickness: 25 ft
 Porosity: 20%
 Permeability: 200 mD
SPE 100004
TANNER, WYOMING
SPE 100004
SOUTHEAST ASIA PROJECTS
•
HEAVY CRUDE
•
HIGH TEMPERATURES
•
ENVIRONMENT CONCERNS
• FRESH WATER SOURCE
SOUTHEAST ASIA PROJECTS
INJECTED, ON-GOING & APPROVED PROJECTS
SS 6-72LV, SS 8020
OFFSHORE ALKALINE
SURFACTANT (AS) PROJECT
 SEA WATER IS SOFTENED ON THE PLATFORM
 SINGLE WELL TEST SUCCESSFULLY PERFORMED
USING SS 6-72LV INJECTED WITH NAOH
 PILOT PROJECT WILL PROCEED
SOUTH AMERICA PROJECTS
•
VARIOUS RESERVOIR CONDITIONS
•
MANY EOR CANDIDATE FIELDS –
OFFSHORE & INLAND
•
ASPHALTENE REMOVAL / WELLBORE
DAMAGE REMOVAL
•
IMPROVED GAS RECOVERY/REDUCED
WATER CUT
SOUTH AMERICA PROJECTS
INJECTED, ON-GOING & APPROVED PROJECTS
ORS-57HF, ORS-41HF (2), SS-6046,
SS GI-1416, SS B1688
as
ORS-41HF (2), ORS62, ORS-97, ORS46HF,ORS-162, SS7593, SS B1688(2)
SS B2080, SS B505,
ORS-46L, ORS97HF, ORS-41HF
SS 77-57
ORS-41(4) *,
SS B1688
SS B8020
SS 6-72
ORS-57HF
ORS-41HF
SSSS-6046,
SS GI1416
ORS-41HF, SS
B1688
ORS-41, SS6566, ORS-57
INJECTED, ON-GOING & APPROVED PROJECTS
PRESENTATION OUTLINE
 Introduction
 EOR – past
 EOR - Oil Chem Technologies
field experience to share
 EOR - future
EOR BY CHEMICAL FLOOD
The future is bright – Reasons?
 High oil prices
 Energy demand
 Diminishing reserves
 Past experience
 New technologies
CHEMICAL EOR - THE FUTURE
 New processes use less surfactant (up to
10 times less)
 Extensive lab evaluations support the
feasibility of chemical flooding
 Field data proves chemical flooding is an
effective way to recover residual oil
 Cost of chemicals have not increased in
proportion to price of crude oil
COST OF CHEMICALS
1980
2006
$3-4/lb
$1/lb
$0.40-0.60/lb
$0.60-1.2/lb
Alkali3
$0.12/lb
$0.20-.040/lb
Crude Oil
$12/bbl
$50-70/bbl
$8-15
$0.50-$5
Polymer1
Surfactant2
Incr. Cost/bbl
1
Some processes eliminate need for polymer
2 Surfactant concentration has been reduced by 10
3 Alkali has been reduced by 50% or in some cases is
not needed at all
PROCESS CHOICES
 Surfactant
 Surfactant Polymer
 Alkaline Surfactant
 Alkaline Surfactant Polymer
 Smart Surfactant
 Pseudo-emulsion
 Chemical/Mechanical
SCALING UP
ENLARGED FIELD CHEMICAL
FLOOD
 Raw Material Supply
• Source (local or import)
• Availability (quantity, quality)
• Alternative suppliers
• Storage
 Manufacturing Location
• Foreign, domestic, on-site
• Shipping, tax, etc.
• Storage and distribution
• Flexibility
ENLARGED FIELD CHEMICAL
FLOOD
 Capital Investment
• Up-front investment
• Operational cost
• By-products
CHEMICAL EOR OPPORTUNITIES
 Conventional Oil Recover Factor <33%
 Oil reserves & reservoir characteristics
have already been confirmed
 Improved processes and chemicals are
available
 Better scaling and modeling has been
developed
CHEMICAL EOR OPPORTUNITIES
 Two trillion bbl of oil remain in depleted or




abandoned wells
Chemical floods offer the only chance in
many depleted & water flooded reservoirs
Chemical EOR must be re-evaluated based on
current technical & economic conditions
Minimal or no remediation is necessary,
minimizing environmental constraints
Trained personnel are available locally
COMPLIMENTARY
SURFACTANT EVALUATION
Total Bill
SS-7593
= $ 0.00
1
IFT, mN/m
To: Oil Chem
Technologies
0.1
0.01
0.001
0
0.1
0.2
0.3
SS-5566, WT%
0.4
0.5
SHARE OUR TECHNOLOGY
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THANK YOU !
Oil Chem Technologies, Inc.
12822 Park One Drive
Sugar Land, TX 77478
281-240-0161
www.oil-chem.com