Transcript information about Polymer Gel use

“AN IMPROVED POLYMER
TECHNOLOGY YIELDS
EXCELLENT RESULTS IN THE
KANSAS ARBUCKLE”
Polymer Services, LLC
 Expertise: Design, field application, and
evaluation of polymer gel treatments in Kansas
since 1989
 Services: Candidate selection and treatment
design, polymer products, laboratory, field
implementation equipment and experienced
crews and project supervision
 Headquarters and Field Offices: Hays, Kansas
What is Polymer Gel?
 Original process developed in the late 1960’s, by
Phillips Petroleum Company (chrome/redox
system)
 Today’s gels are created when polymer is mixed
in water and cross linked with a trivalent
chromium ion
 Polymer and crosslinker mixed on the surface as
opposed to previous systems that mix in the
reservoir
 Gel Strength is a function of polymer
concentration
Continued:
What is Polymer Gel?
 Gels having viscosity slightly greater than fresh
water to rubber can be created in virtually any
water, at temperatures up to 270 F, in high TDS,
H²O and CO² environments
 Used to shut off unwanted water in producing oil
and gas wells, and to improve conformance at
water/CO² injection wells
 Considered to be permanent after placement
 Special equipment is normally required to
properly blend and pump polymer gels
Modern Chemistry Options
 Recent advances in gel chemistry are largely
responsible for the current high success rate in
the Kansas Arbuckle
 The key to current successes is the use of
chromium III gel systems as opposed to older
crosslinking technologies
 Two crosslinking systems (both chromium III)
have contributed to the current successful
treatments in Kansas
Continued:
Modern Chemistry Options
The current systems used in Kansas are
the MARCIT® system developed by
Marathon Oil Company and the PROD®
system developed by ChevronPhillips
Chemical Company
Polymer jobs in the Arbuckle today
compared to what has been done
in the past?
 Today’s gels are more stable in a wide range of
pH, high temperature, high H²S, salinity and high
TDS environments
 Only two chemicals are required to form the gel
 Chemicals are now mixed on the surface rather
than in the reservoir
 Today’s treatments are much larger in volume
Well candidate selection criteria
 Significant remaining mobile hydrocarbons in
place (cumulative production history is usually a
good indication)
 Wells producing at or near their economic limit
due to costs associated with excessive water
production
 High water disposal and/or lifting costs
 Producers in natural waterdrive reservoirs
Continued:
Well candidate selection criteria
 Producers in water floods are treatable, but
recommend treating injectors
 Better chance of increasing oil production when
treating wells that have high producing fluid
levels
 High permeability contrast between oil and water
saturated rock
 Vuggy and/or fractured reservoir
Key Factors
in designing gel treatments
 The type of gel polymer/crosslinker and
concentration
 Treatment volume
 Treating procedure
Treatment Design Information
 Wellbore schematic/data
Tubing size & depth, casing size & depth,
perforated/openhole depths, beam or submersible
pump, etc.
 Porosity/electric logs
 Core reports
 Oil and Water production history
 Fluid pump-in data from acid jobs or other work
 Cumulative recovery map
 Structure/isopach map
 Oil price and water handling cost
Sizing the Treatment
 DISTANCE…
Radial flow calculation
50-200 Bbls. Per porosity-foot (depends on
well productivity)
VOLUME…
Estimate daily capacity of well to produce fluid
at maximum draw-down, then use that volume
to determine gel treatment volume
Need static and producing FL, and producing
rate(s)
Before Pumping the Job
 Ensure that the wellbore is clean, sand pump or
otherwise clean out well to original TD..
 An AGGRESSIVE acid cleanup treatment has
proven to be very effective (1500-3000 gallons 15% NEFE,
pump away with water at high rate)
 Establish a maximum treating pressure. Use
calculated frac gradient for field or run step-rate
test if necessary
Continued:
Before Pumping the Job
 Select an acceptable source of water that will
be used to blend and pump the treatment
(fresh. Kcl, or clean produced water which has been tested for polymer
compatibility prior to treatment)
 Select a polymer-compatible biocide for mix
water (mix at concentration recommended by
the supplier)
 Set packer on tubing to isolate zone to be
treated
Pressure Monitoring During
Treatment
Pressure
0
200
400
Rate
600
800
PPM
1,000
PSI/BWI
1,200
1,400
8000
1,600
1.20
7000
1.00
6000
5000
0.60
4000
3000
0.40
2000
0.20
1000
0.00
0
0
200
400
600
800
1,000
-1000
1,200
1,400
1,600
-0.20
CUMULATIVE BWI
PSI/BWI
RATE & PRESSURE
0.80
Polymer Services, LLC., has used
ChevronPhillips technology on 42
producing oil wells, 2 producing
gas wells, and one injection well
since January 1, 2003. A brief
summary of the treatments and
results is as follows.
Well #1
Mississippi dolomite formation
Ness County, Ks
 Treatment was 450 bbl WATER-BLOCK 247
 Pumped January 3, 2003
 Production before treatment:
 3 BOPD, 185 BWPD
 Initial production after treatment:
 30 BOPD, 110 BWPD. Pumped off
 Current production:
 12 BOPD, 98 BWPD. Pumped off
Production before
treatment
Well Production
200
180
160
140
Initial production
After treatment
120
100
80
60
40
20
0
BOPD
BWPD
Current production
Well #2
Arbuckle dolomite formation
Rush County, Ks
 Treatment was 185 bbl WATER-BLOCK 247
 Pumped on January 5, 2003
 Production before treatment:
 3 BOPD, 185 BWPD
 Initial production after treatment:
 30 BOPD, 110 BWPD. Pumped off
 Current production:
 22 BOPD, 118 BWPD. Pumped off
Production before
treatment
Well Production
200
180
160
140
Initial production
After treatment
120
100
80
60
40
20
0
BOPD
BWPD
Current production
Well #3
Gorham sand formation
Russell County, Ks
(Trapp Field)
 Treatment was 70 bbl WATER-BLOCK 247
 Pumped on January 7, 2003
 Production before treatment:
 5-6 BOPD, 1100 BWPD
 Current production:
 2-3 BOPD, 180 BWPD. Pumped off
Well Production
Production before
treatment
1200
1000
800
600
Current production
400
200
0
BOPD
BWPD
Well #4
Arbuckle dolomite
Rush County, KS
(Hampton SE)
Treatment was 595 bbl Water-Block 247
Pumped on January 9, 2003
Production before treatment:
 5-6 BOPD, 1100 BWPD
Initial production after treatment:
 15 BOPD, 165 BWPD
Current Production
 12 BOPD, 205 BWPD
Well Production
1200
Production before
treatment
1000
800
600
400
Initial production
After treatment
200
0
BOPD
BWPD
Current production
Well #5
Lansing-Kansas City Limestone
Formation
Ellis County, KS (Munjor)
 Treatment was 50 bbl WATER-BLOCK 247
 Pumped on January 10, 2003
 Purpose was to divert injected water from thief
zone to sweep tighter zones
 Injection rate on vacuum has been reduced from
180 BWIPD to 80 BWIPD, with slight
improvement in oil-water ration on affected
producing well
Well #6
Arbuckle dolomite formation
Graham County, Ks
(Morel Field)
 Treatment was 4150 bbl WATER-BLOCK 247
 Pumped on January 12-16, 2003
 Production before treatment:
 8 BOPD, 900 BWPD
 Initial production after treatment:
 46 BOPD, 84 BWPD
 Current production:
 12 BOPD, 160 BWPD
Production before
treatment
Well Production
900
800
700
600
500
400
300
200
Initial production
After treatment
100
0
BOPD
BWPD
Current production
Well #7
Arbuckle dolomite formation
Rooks County, Ks
(Westhusin Field)
 Treatment was 1520 bbl WATER-BLOCK 247
 Pumped January 25-26, 2003
 Production before treatment:
 8 BOPD, 900 BWPD
 Initial production after treatment:
 48 BOPD, 100 BWPD
 Current production:
 22 BOPD, 200 BWPD
Production before
treatment
Well Production
900
800
700
600
500
400
300
200
Current production
Initial production
After treatment
100
0
BOPD
BWPD
Well #8
Dolomite formation
Rooks County, Ks
(Hrabe Field)
 Treatment was 1204 bbl WATER-BLOCK 247
 Pumped January 27-28, 2003
 Production before treatment:
 7 BOPD, 900 BWPD
 Initial production after treatment:
 33 BOPD, 177 BWPD
 Current production:
 15 BOPD, 195 BWPD
Production before
treatment
Well Production
900
800
700
600
500
400
300
Initial production
after treatment
200
100
0
BOPD
BWPD
Current production
Well #10
Lansing-Kansas City limestone
Graham County, Ks
 Treatment was 200 bbl WATER-BLOCK 247
over 3 separate intervals
 Production before treatment:
 4 BOPD, 510 BWPD
 Initial production after treatment:
 27 BOPD, 52 BWPD, Pumped off
 Current production:
 12 BOPD, 48 BWPD
Well Production
600
Production before
treatment
500
400
300
200
Initial production
After treatment
100
0
BOPD
BWPD
Current production
Well #12
Viola limestone
Comanche County, Ks
 Treatment was 425 bbl WATER-BLOCK 247
 Pumped March 6, 2003
 Production before treatment:
 50 mcf gas, 900+ BWPD
 Current production:
 450 mcf gas, 250 BWPD
Well Production
Production before
treatment
900
800
700
Current production
600
500
400
300
200
100
0
BOPD
BWPD
Well #13
Arbuckle dolomite
Ellis County, Ks
(Bemis-Shutts Field)
 Treatment was 4025 bbl WATER-BLOCK 247
 Pumped March 31 – April 3, 2003
 Production before treatment:
 3 BOPD, 700 BWPD
 Initial production after treatment:
 184 BOPD, 46 BWPD
 1 month production:
 79 BOPD, 36 BWPD
 Current production:
 35 BOPD, 80 BWPD
Production before
treatment
Well Production
700
600
500
400
300
Initial production
After treatment
1 month production
200
100
0
BOPD
BWPD
Current production
Well #14
Arbuckle dolomite
Ellis County, Ks
(Bemis-Shutts Field)
 Treatment was 955 bbl WATER-BLOCK 247
 Pumped April 8-9, 2003
 Production before treatment:
 3 BOPD, 950 BWPD
 Initial production after treatment:
 80.6 BOPD, 439.4 BWPD
 1month production:
 40 BOPD, 22 BWPD
 Current production:
 12 BOPD, 128 BWPD
Production before
treatment
Well Production
1000
900
800
700
600
Initial production
After treatment
500
400
300
Current production
1 month production
200
100
0
BOPD
BWPD
Well #16
Arbuckle dolomite
Rooks County, Ks
(Northampton Field)
 Treatment was 5100 bbl WATERBLOCK - 247
 Production before treatment:
 6 BOPD, 650 BWPD
 Initial production after treatment:
 85 BOPD, 100 BWPD
 Current production:
 55 BOPD, 135 BWPD
Well Production
Production before
treatment
700
600
500
400
300
200
Initial production
After treatment
100
0
BOPD
BWPD
Current production
J-F Oil Company
Bemis C #7
Arbuckle dolomite formation
Ellis County, Ks
 Treatment was 5100 bbl WATER-BLOCK 247
 Pumped February 28 – March 6, 2003
 Production before treatment:
 12 BOPD, 3200 BWPD
 Initial production after treatment:
 141 BOPD, 69 BWPD
 Current production:
 12 BOPD, 192 BWPD
Well Production
3500
Production before
treatment
3000
2500
2000
1500
1000
500
Initial production
After production
0
BOPD
BWPD
Current production
Noble Petroleum
Rathbun #8
Treatment was 5100 bbl WATERBLOCK247, April 28th, 2003
Production before treatment:
5 BOPD, 650 BWPD
Initial production after treatment:
27 BOPD, 153 BWPD
Current production:
55 BOPD, 125 BWPD
Well Production
700
Production before
treatment
600
500
400
300
Initial production
after treatment
200
100
0
BOPD
BWPD
Current production
Rooks County
Arbuckle dolomite
Treatment was 1150 bbl WATERBLOCK –
247, May 28th, 2003
Production before treatment:
3 BOPD, 950 BWPD
Initial production after treatment:
210 BOPD, 20 BWPD
Current production:
86 BOPD, 114 BWPD
Production before
treatment
Well Production
1000
900
800
700
600
500
400
300
Initial production
After treatment
Current production
200
100
0
BOPD
BWPD
White Eagle Resources
Carmichael A #4
Treatment was 5100 bbl WATERBLOCK 247, June 10th, 2003
Production before treatment:
9 BOPD, 3600 BWPD
Initial production after treatment:
70 BOPD, 130 BWPD
Current production:
55 BOPD, 145 BWPD
Well Production
4000
Production before
treatment
3500
3000
2500
2000
1500
1000
Initial production
After treatment
500
0
BOPD
BWPD
Current production
Rooks County
Arbuckle dolomite
Treatment was 2820 bbl WATERBLOCK –
247, June 15th, 2003
Production before treatment:
3 BOPD, 950 BWPD
Current production:
187 BOPD, 113 BWPD
Well Production
1000
Production before
treatment
900
800
700
600
500
400
Current production
300
200
100
0
BOPD
BWPD
Noble Petroleum
Rathbun #3
Treatment was 3600 bbl WATERBLOCK –
247, June 19th, 2003
Production before treatment:
7 BOPD, 750 BWPD
Initial production after treatment:
 55 BOPD, 125 BWPD
Current production:
71 BOPD, 87 BWPD
Well Production
Production before
treatment
800
700
600
500
400
300
200
Initial production
After treatment
100
0
BOPD
BWPD
Current production
Rooks County
Northampton Field
Treatment was 3660 bbl WATERBLOCK –
247, June 26th, 2003
Production before treatment:
3 BOPD, 950 BWPD
Initial production after treatment:
132 BOPD, 90 BWPD
Current production:
121 BOPD, 111 BWPD
Well Production
1000
Production before
treatment
900
800
700
600
500
400
300
Initial production
After treatment
200
100
0
BOPD
BWPD
Current production
Graham County
Morel Field
Treatment was 1400 bbl WATERBLOCK –
247, May 17th, 2003
Production before treatment:
3 BOPD, 300+ BWPD
Initial production after treatment:
168 BOPD, 12 BWPD
Current production:
21 BOPD, 59 BWPD (pumped off)
Production
Before treatment
Well Production
300
250
Initial production
After treatment
200
150
Current production
100
50
0
BOPD
BWPD
Polymer Water Shutoff Treatments
Problem:
 Excessive water production (typical candidate
well producing 500-5000 BWPD)
 .5 thru 2% Oil cut
 High producing fluid levels
 High electricity costs ranging from $600 to
$6000/month per well
 Wells shut in due to lack of disposal capacity /
high lifting costs
Continued:
Polymer Water Shutoff Treatments
Solution:
Polymer water shut-off get treatments
were designed & pumped based on
candidate selection criteria, available well
data and experience with similar wells in
the area
Treatment size ranged from 210 BBL to
over 6000 BBL Waterblock 247,
depending on individual well conditions
Continued:
Polymer Water Shutoff Treatments
Result:
 Average water production per well was reduced 7590%
 Daily oil rate (BOPD) typically increases from 50% to
more than 60 times the original production
 Incremental oil production ranges from 800 to 5400
barrels of oil per month have been reported
 Electricity savings ranges from $500 to $3500/month
per well
Conclusions
Improved polymer gel technology has
vastly improved results in the Kansas
Arbuckle
The improved results can largely be
attributed to the following changes which
have occurred in the past few years:
A transition from older crosslinking technology
to the current chromium III gel technologies,
which have become the standard
Continued:
Conclusions
The current chromium III technologies are the
MARCIT® technology developed by Marathon
Oil Company and the PROD® developed by
ChevronPhillips Chemical Company
Both of these technologies are field proven
and have yielded similar results in the Kansas
Arbuckle
In addition to the improvements in gel
chemistry, much has been learned about
candidate selection, treatment design, and
implementation
Continued:
Conclusions
The above circumstances have led to
much greater success rates and
incremental oil recoveries from polymer
gel applications in the Kansas Arbuckle