CHEMICAL EOR CHEMICAL EOR FIELD EXPERIENCE FIELD EXPERIENCE Oil Chem Technologies, Inc. Oil Chem Technologies, Inc. Sugar Land, TX USA www.oil-chem.com
65
Embed
CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc. CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc. Sugar Land, TX USA .
This document is posted to help you gain knowledge. Please leave a comment to let me know what you think about it! Share it to your friends and learn new things together.
Transcript
Slide 1
CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc.
CHEMICAL EOR FIELD EXPERIENCE Oil Chem Technologies, Inc. Sugar
Land, TX USA www.oil-chem.com
Slide 2
PRESENTATION OUTLINE Introduction to Oil Chem EOR past EOR -
Oil Chem Technologies field experience to share EOR - future
Slide 3
PRESENTATION OUTLINE Introduction EOR past EOR - Oil Chem
Technologies field experience to share EOR - future
Slide 4
WHY EOR?
Slide 5
Oil Recovery Overview BAVIER; BASIC CONCEPTS OF EOR
PROCESSES(1991)
Slide 6
WHY CHEMICAL EOR?
Slide 7
ECONOMICS FOR FIELD ASP PROJECTS Field W. Kiehl CambridgeDaqing
Surfactant0.10%0.10%0.30% Alkali0.80%1.25%1.00% Polymer 1050 ppm
1425 ppm 1200 ppm Tot. Cost $375,000$2,518,000$1,009,000 Inc. ASP
Oil 275,0001,143,000270,000 Cost/bbl$1.46$2.20$3.79
Slide 8
ROLE OF SURFACTANTS Reduce interfacial tension Wettability
alteration Polymer, CDG, BW, etc. can be used along with
surfactants when mobility control is necessary
RELATIONSHIP BETWEEN CAPILLARY NUMBER AND OIL RECOVERY Nc = /
cos Nc = Capillary Number = Darcy Velocity = Darcy Velocity =
Viscosity = Interfacial Tension =wetting angle
Slide 11
PRESENTATION OUTLINE Introduction EOR past EOR - Oil Chem
Technologies field experience to share EOR - future
Slide 12
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
Slide 13
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
Slide 14
CHEMICAL EOR - PAST PROBLEMS Technical success but limited
commercial success - Reasons?
Slide 15
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
Slide 16
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
Slide 17
PRESENTATION OUTLINE Introduction EOR past EOR - Oil Chem
Technologies field experience to share EOR - future
Slide 18
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
Slide 19
CHINA EOR PROJECTS Heavy crude recovery Heavy crude recovery
Low perm formation oil recovery Low perm formation oil recovery
High temp. / high salinities High temp. / high salinities
Effective, economical offshore EOR Effective, economical offshore
EOR
Slide 20
CHINA EOR PROJECTS INJECTED, ON-GOING & APPROVED PROJECTS
SS B2080, SS B5050, SS B1688, ORS-46L, ORS-97HF, ORS-41HF
Slide 21
1992-94: LAB EVALUATION 1992-94: LAB EVALUATION Over 100
Surfactants Were Tested Over 100 Surfactants Were Tested Including:
Including: ORS-41 Petroleum Sulfonates Carboxylates Lignin
Sulfonate/Petroleum Sulfonates Microbiological
Slide 22
1995 - INITIAL FIELD 1995 - INITIAL FIELD EVALUATION EVALUATION
Daqing No.4 Field - Oil Chem Technologies ORS-41 Technologies
ORS-41 Daqing No.1 Field another US companys Petroleum
Sulfonate
Slide 23
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 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
Slide 24
Slide 25
DAQING CENTRAL WELL SPE 57288
Slide 26
DAQING CENTRAL FIELD SPE 84896
Slide 27
HEAVY OIL RECOVERY BY CREATING WATER EXTERNAL PSEUDO-
EMULSION
Slide 28
Control 0.1% SF-100 Surfactant HEAVY OIL PSEUDO-EMULSION
Slide 29
Control 0.1% SF-100 Surfactant HEAVY OIL PSEUDO-EMULSION
Slide 30
Control 0.1% SF-100 Surfactant HEAVY OIL PSEUDO-EMULSION Oil
Viscosity < 200 cps Oil Viscosity = 6,700 cps
Slide 31
LAB CORE FLOOD DATA Water flood Injection Volume, PV Oil
Recovery, %
Slide 32
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
Slide 33
CANADA EOR PROJECTS HEAVY CRUDE HEAVY CRUDE TAR SAND TAR SAND
LOWER RESERVOIR TEMPERATURES LOWER RESERVOIR TEMPERATURES FRESH
WATER SOURCES FRESH WATER SOURCES HIGH SALINITY RESERVOIRS HIGH
SALINITY RESERVOIRS FRACTURED CARBONATE FORMATIONS FRACTURED
CARBONATE FORMATIONS
Slide 34
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
Slide 35
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%
Slide 36
UNITED STATES EOR PROJECTS FRESH WATER SOURCES FRESH WATER
SOURCES HIGH SALINITY RESERVOIRS HIGH SALINITY RESERVOIRS FRACTURED
CARBONATE FORMATIONS FRACTURED CARBONATE FORMATIONS LOW
PERMEABILITY LOW PERMEABILITY
Slide 37
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)
Slide 38
SHO-VEL-TUM FIELD On production > 40 yrs, extensive water
flood, produced 4 bbl/day ASP started on 2/98, using Na 2 CO 3 and
ORS- 62 Total incremental oil > 10,444 bbl (22 bbls/day) in 1.3
years SPE 84904
Slide 39
OIL SATURATION AFTER ASP INJECTION SPE 84904
Slide 40
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
Slide 41
MELLOTT RANCH ASP PROJECT - ORS-46HF ASP WATER FLOOD SINCE
1966
Slide 42
BIG SINKING, KENTUCKY Project Information Crude oil : 100
Million bbl Bottom Hole Temperature: 30 o C Depth: 1150 ft
Thickness: 25 feet (7.32 meter) Permeability: 45 mD SPE 100004
Slide 43
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
Slide 44
BIG SINKING, KENTUCKY SPE 89384
Slide 45
TANNER FIELD, WYOMING Project Information Crude oil : 21 o API
Bottom Hole Temperature: 175 o F Depth: 8915 ft Thickness: 25 ft
Porosity: 20% Permeability: 200 mD SPE 100004
Slide 46
TANNER, WYOMING SPE 100004
Slide 47
SOUTHEAST ASIA PROJECTS HEAVY CRUDE HEAVY CRUDE HIGH
TEMPERATURES HIGH TEMPERATURES ENVIRONMENT CONCERNS ENVIRONMENT
CONCERNS FRESH WATER SOURCE FRESH WATER SOURCE
Slide 48
SOUTHEAST ASIA PROJECTS INJECTED, ON-GOING & APPROVED
PROJECTS SS 6-72LV, SS 8020
Slide 49
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
Slide 50
SOUTH AMERICA PROJECTS VARIOUS RESERVOIR CONDITIONS VARIOUS
RESERVOIR CONDITIONS MANY EOR CANDIDATE FIELDS MANY EOR CANDIDATE
FIELDS OFFSHORE & INLAND OFFSHORE & INLAND ASPHALTENE
REMOVAL / WELLBORE ASPHALTENE REMOVAL / WELLBORE DAMAGE REMOVAL
DAMAGE REMOVAL IMPROVED GAS RECOVERY/REDUCED IMPROVED GAS
RECOVERY/REDUCED WATER CUT WATER CUT
Slide 51
SOUTH AMERICA PROJECTS INJECTED, ON-GOING & APPROVED
PROJECTS ORS-57HF, ORS-41HF (2), SS-6046, SS GI-1416, SS B1688
Slide 52
as
Slide 53
PRESENTATION OUTLINE Introduction EOR past EOR - Oil Chem
Technologies field experience to share EOR - future
Slide 54
The future is bright Reasons? The future is bright Reasons?
High oil prices Energy demand Diminishing reserves Past experience
New technologies EOR BY CHEMICAL FLOOD
Slide 55
New processes use less surfactant (up to 10 times less) 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 CHEMICAL EOR - THE
FUTURE
Slide 56
COST OF CHEMICALS 19802006 Polymer 1 $3-4/lb$1/lb Surfactant 2
$0.40-0.60/lb$0.60-1.2/lb Alkali 3 $0.12/lb$0.20-.040/lb Crude Oil
$12/bbl$50-70/bbl Incr. Cost/bbl $8-15$0.50-$5 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 not needed at all
ENLARGED FIELD CHEMICAL FLOOD Raw Material Supply Source (local
or import) Source (local or import) Availability (quantity,
quality) Availability (quantity, quality) Alternative suppliers
Alternative suppliers Storage Storage Manufacturing Location
Foreign, domestic, on-site Foreign, domestic, on-site Shipping,
tax, etc. Shipping, tax, etc. Storage and distribution Storage and
distribution Flexibility Flexibility
Slide 60
ENLARGED FIELD CHEMICAL FLOOD Capital Investment Up-front
investmentUp-front investment Operational costOperational cost
By-products By-products
Slide 61
CHEMICAL EOR OPPORTUNITIES Conventional Oil Recover Factor