PFS Brochure

Professional fluid services, llc

PRODUCT LINE
TECHNOLOGY

QUALITY

AND

TRUST

For Additional Information
Please Visit Our Web Site
at
www.professionalfluid.com ENGINEERED SOLUTIONS FOR:
LOSS CIRCULATION MATERIALS
CROSS LINK POLYMER TECHNOLOGY
CEMENT SPACERS
WIRE LINE CEMENT AND RESIN KITS
24 Hour Telephone: RESIN SYSTEMS
888.862.7177
CEMENT ADDITIVES
Fax: 337.984.6652
LAB TESTING
E-mail:
pfsllc@ultrasealinc.com
ON SITE CONSULTING

Professional Fluid Services, LLC

TABLE OF CONTENTS

Section 1: Loss Circulation Materials
Ultra Seal® XP Page 2, 4 & 6
Ultra Seal® C Page 3, 5 & 6
Ultra Seal® TG Page 7 & 8
Ultra Seal® Plus Page 9 & 10
Pro Seal® Fine Page 11 & 13
Pro Seal® Coarse Page 12
Recommended Treatments Page 14
Particle Size Distribution Ultra Seal® XP and Ultra Seal® TG Page 15
Particle Size Distribution Ultra Seal® C and Ultra Seal® Plus Page 16
Section 2: Cross Link Polymer Technology
Poly Plug® Page 17, 18 & 19
Poly Plug® (CLEAR GEL) Page 20 & 21
Ultra Squeeze® Page 22 & 23
Section 3: Cement Spacer
Ultra Spacer® Page 24,25 & 26
Ultra Surf® Page 27
Ultra Spacer® Case Histories Page 28-32
Section 4: Wire Line Kits
Ultra Bond® Page 33-34
Ultra Set® Page 35-36
Pro Bond™ Page 37
Pro Bond™ SSW Page 38
Ultra Seal® S (SEALANT) Page 39
Liquid Bridge Plug® Page 40
Section 5: Resin
Liquid Bridge Plug® Page 41
Section 6: Cement Additives
GMA #1 (GAS MIGRATION ADDITIVE) Page 42
ECT® KIT Page 43
Section 7: Customer List
References Page 44
Section 8: Services
Lab Testing Page 45
On Site Consulting (Cement and Water Shut Off) Page 45

P.O. Box 80293 · Lafayette Louisiana 70598 · Telephone: (888) 862-7177 · www.professionalfluid.com

ULTRA SEAL®
Professional Fluid Services, LLC

AUGUST 2006

PRODUCT DESCRIPTION PRODUCT DATA
SHEETS
Unlike most fiber That's one reason why
products, Ultra Seal-XP® Ultra Seal® is available
is a blend of different ULTRA SEAL-XP®
in four different product
types of cellulose fiber grades: Ultra Seal® XP
groups, filtrate control & Ultra Seal® TG SCM
agents and physical ULTRA SEAL-TG®
is a fine-grade material
lubricants, not just one often used as a
primary fiber type. Both preventative; Ultra
laboratory testing and ULTRA SEAL-C®
Seal® C LCM is a
experience on the rigs
similar product
continues to prove that
manufactured in a
the unique Ultra Seal®
ULTRA SEAL-PLUS®
course grade required
blend provides consis-
for severe or total loss of
tently superior
returns; Ultra Seal®
performance.
PRO SEAL® FINE
Plus LCM is a
Every drilling situation is proprietary blend of
different, so there is no fibrous, granular and
single answer to loss PRO SEAL® COARSE
flake materials designed
circulation problems. specifically for massive
loss circulation.

Special Points of
Interest:
• Excellent for Controlling
Differential Sticking
demand more efficient,
PRODUCT BENEFITS • Seals Micro-Fractured
cost effective
operations, the need to Shale
minimize lost-time, such
• Reduces Torque & Drag
as differential sticking
tests, Ultra Seal® DFA is
Due to the extensive • Solves Loss Circulation
and loss circulation, has
research required to the most effective and
• 90-100% Return Perm
become imperative. By
develop the Ultra Seal® cost efficient drilling fluid
using Ultra Seal® DFA ,
• 70% Soluble in Bleach
DFA product line, the additive of its type on
many drilling related
quality of raw materials the market today.
problems can be
selected for the As the oil and gas prevented and
manufacturing process industry worldwide controlled.
and the conducting of continues to demand
numerous quality control

PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com Page: 2

ULTRA SEAL-XP® SCM(FINE)
DESCRIPTION: Ultra Seal® XP is CONCENTRATIONS:
a blend of specific micro sized Differential Sticking Prevention:
cellulosic fibers combined with a For excessive torque and drag,
blend of organic polymers and sweeps of 8-25 lbs/bbl of Ultra
lubricity enhancers. Seal® XP is recommended. For
APPLICATION: Ultra Seal® XP is extended intervals, Ultra Seal® XP
designed to aid in the control of can be added system wide in
fluid losses to the well bore, as well concentrations of 4-8 lbs/bbl.
as promote the anti friction Seepage Control:
characteristics of a drilling fluid.
Sweeps of 12-25 lbs/bbl of Ultra
Ultra Seal® seals off low pressure Seal® XP combined with up to
zones, which in turn reduces rotary 12.5 lbs/bbl Ultra Seal® C is
torque and drill string drag that is recommended.
present in these differential
Packaging: 25 lb sacks, 48 per
pressure environments.
pallet.
Ultra Seal® XP is compatible with
both OBM and WBM systems and
is coated with a mineral oil.

ULTRA SEAL-C® LCM (MEDIUM)
“If ULTRA SEAL® C or ULTRA
DESCRIPTION: Ultra Seal® C is CONCENTRATIONS:
a blend of cellulose vegetable SEAL® Plus is not successful in
Partial Losses:
fibers and is blended in a medium
solving the loss circulation
Sweeps/spots of Ultra Seal® C in
to coarse grade. The product is
problem, consider the use of
concentrations of 25 lbs/bbl in
coated with a food grade mineral
POLY PLUG®. See POLY PLUG®
addition to 12.5 lbs/bbl of
oil and is compatible with both
Ultra Seal® C is recommended
WBM and OBM systems. product data sheet for more
across the loss zone.
information.”
APPLICATION: Ultra Seal® C is
Total Losses:
applied in the form of sweeps or
spots within the active drilling fluid. A 50-100 bbl pill of Ultra Seal® C
along with 40-60 lbs/bbl Ultra Packaging: 11.36 kg sacks, 42
Seal® Plus should be mixed in the sacks per pallet.
slugging tank and spotted across
the loss zone.

ULTRA SEAL-PLUS® LCM (COARSE)
DESCRIPTION: A blend of Ultra CONCENTRATIONS:
Seal® XP , Ultra Seal C® and Loss Circulation:
additional (larger) sealing agents.
A 50-100 bbl pill of 40-60 lbs/bbl
The large particle array is
Ultra Seal® Plus should be mixed
beneficial in establishing a stronger
and spotted across the loss zone.
initial bridge across the thief zone.
By the inclusion of these larger
particles, effective control of rigid Packaging: 40 lb sacks, 28 sacks
type fractures, vugular or per pallet.
unconsolidated formations can be
achieved. Ultra Seal® Plus is the
LCM portion of POLY PLUG®

Page: 3
PO Box 80293 · Lafayette LA 70598 · Phone: (888)-862-7177 · www.professionalfluid.com

PRODUCT DATA SHEET

ULTRA SEAL® XP
DESCRIPTION:

Ultra Seal® XP is a patented blend of specific micro sized cellulose fibers, combined with a
blend of organic polymers and lubricity enhancers. Ultra Seal® XP is compatible with both
water and oil base mud systems.

USES:

SEALING MICRO FRACTURED SHALES
SEEPAGE CONTROL
TORQUE AND DRAG REDUCTION DIFFERENTIAL STICKING PREVENTION

FEATURES:

Ultra Seal® XP is designed to aid in the control of fluid losses to the well bore, as well as
promote the anti-friction characteristics of a drilling fluid.

Ultra Seal® XP seals of low pressure zones, which in turn reduces rotary torque and drill string
drag that is present in these differential pressure environments.

Ultra Seal® XP inhibits seepage loss to the formation, as well as restricting flow into depleted
sands.

TREATMENT:
Ultra Seal® XP is used in concentrations of 4-25 lbs/bbl.

PACKAGING:
25 lbs net weight in multi-wall paper bags.
( 48 bags per 44quot;X44quot; pallet)

Page: 4


PRODUCT DATA SHEET

ULTRA SEAL® C
DESCRIPTION:

Ultra Seal® C is a patented four particle blend of specific sized cellulose fibers, compatible
with both water and oil base mud systems.

USES:

LOST CIRCULATION

FEATURES:

Ultra Seal® C has a broad particle size distribution and is designed to solve partial to total loss
circulation.

Ultra Seal® C is applied in the forms of sweeps and spots and is mixed with the active mud
system.

TREATMENT:
Ultra Seal® C is used in concentrations of 25-50 lbs/bbl.

PACKAGING:

Page: 5


CASE HISTORY LOCATION:
ULTRA SEAL-XP and ULTRA SEAL-C® Gulf Coast

Page: 6


PRODUCT DATA SHEET

ULTRA SEAL-TG®
DESCRIPTION:

Ultra Seal-TG® is a specific micro sized cellulose fibers, compatible with both water and oil
base mud systems.

USES:

SEALING MICRO FRACTURED SHALES
SEEPAGE CONTROL
TORQUE AND DRAG REDUCTION DIFFERENTIAL STICKING PREVENTION

FEATURES:

Ultra Seal-TG® is designed to aid in the control of fluid losses to the well bore, as well as

Ultra Seal-TG® seals of low pressure zones, which in turn reduces rotary torque and drill string

Ultra Seal-TG® inhibits seepage loss to the formation, as well as restricting flow into depleted
sands.

TREATMENT:
Ultra Seal-TG® is used in concentrations of 4-25 lbs/bbl.

PACKAGING:
25 lb net weight in multi-wall paper bags.

Page: 7

CASE HISTORY

ULTRA SEAL-TG®

LOCATION: EAST CAMERON AREA, GULF OF MEXICO

FLUID TYPE: DIESEL OIL BASE, 16.0 LB/GAL

An offshore Operator was making an open hole displacement of a water base
system with a diesel oil base system when complete loss of returns occurred.
Several attempts were made to regain circulation with competitive types of loss
circulation materials. None of these attempts were successful. A 100 bbl sweep of
Ultra Seal® TG, 25 lb/bbl concentration, was pumped around and full circulation
regained. Final displacement was made and drilling resumed.

The hole was then swept on a regular basis to control any seepage losses. Prior to
logging the well a pill of Ultra Seal® TG was spotted on bottom to aid in control of any
differential sand problems. Another pill was left on bottom during subsequent
production pipe run. No problems were encountered during these procedures.

Page: 8

PRODUCT DATA SHEET

ULTRA SEAL-PLUS®
DESCRIPTION:

A patented blend of fibrous, granular and flake materials designed specifically for massive
loss of circulation. This product was formulated to expand the existing positive qualities of the
Ultra Seal® product line.

USES:

LOSS CIRCULATION

FEATURES:

Ultra Seal® Plus is a blend of Ultra Seal® XP, Ultra Seal® C and additional larger, sealing
agents. This blend expands the superior range of particle sizes that are consistent with the
existing product line.

By the inclusion of these larger particles, effective control of rigid type fractures, vugular or
unconsolidated formations and highly permeable thief zones can be achieved.

TREATMENT:
Ultra Seal® Plus is used in concentrations of 40-60 lbs/bbl.

PACKAGING:

Page: 9

CASE HISTORY

ULTRA SEAL-PLUS®

LOCATION: VERMILLION BLOCK 45 B-4

FLUID TYPE: Water Base Mud

By sweeping the hole with Ultra Seal® Plus, a project TD of (9,654’) was reached
without incident of differential sticking or loss circulation. Sands encountered
from surface pipe to TD had formation pressures from 6.6 ppg to normal pressure.

Ultra Seal® Plus was used in concentrations of 25 ppb and pumped every
connection to prevent loss circulation and differential sticking. A 10 ppg mud
weight was required at TD.

Page: 10

PRODUCT DATA SHEET

PRO SEAL® FINE

DESCRIPTION:
A water base or oil base compatible LCM product with a combination of vegetable and cellulose
fibers. Pro Seal® Fine is coated with a food grade mineral oil to preferentially oil wet the
product.

USES:

SEEPAGE CONTROL LOSS CIRCULATION
TORQUE AND DRAG REDUCTION PREVENTION OF DIFFERENTIAL STICKING

FEATURES:

Pro Seal® Fine is designed to aid in the control of fluid losses to the well bore, as well as

Pro Seal® Fine seals of low pressure zones, which in turn reduces rotary torque and drill string

Pro Seal® Fine inhibits seepage loss to the formation, as well as restricting flow into depleted
sands.

TREATMENT:
Pro Seal® Fine is used in concentrations of 4-25 lbs/bbl.

PACKAGING:
25 & 50 lbs net weight in multi-wall paper bags.

Page: 11

PRODUCT DATA SHEET

PRO SEAL® COARSE

DESCRIPTION:
A water base or oil base compatible 4 particle size LCM product with a combination of vegetable
and cellulose fibers. Pro Seal® Coarse is coated with a food grade mineral oil to preferentially
oil wet the product.

USES:

SEEPAGE CONTROL LOSS CIRCULATION

FEATURES:

Pro Seal® Coarse has a broad particle size distribution and is designed to solve partial to total
loss circulation.

Pro Seal® Coarse is applied in the forms of sweeps and spots and is mixed with the active mud
system.

TREATMENT:
Pro Seal® Coarse is used in concentrations of 25-50 lbs/bbl.

PACKAGING:

Page: 12

CASE HISTORY

PRO SEAL®

LOCATION: Buffalo, Texas

FLUID TYPE: Water Base Mud

The well was experiencing total loss circulation into a depleted sand. Various
attempts to solve the losses with conventional LCM had failed. A 60 bbl pill with
10 ppb Pro Seal® Fine and 40 ppb Pro Seal® Coarse was mixed and spotted
across the zone. The pill was allowed to soak for several hours before attempting
to break circulation. After several hours the well was circulated with full returns.

As a preventative measure, Pro Seal® Fine was added system wide at 6 ppb and
maintained for the duration of the interval. No further losses were noted.

Page: 13

GENERAL MIXING RECOMMENDATIONS

RECOMMENDED TREATMENTS

SEEPAGE LOSS (0-10 bbl’s per hour):

Mix 12.5 lb/bbl of Ultra Seal® XP into the mud system and sweep the hole. In oil base mud
systems Ultra Seal® TG can be substituted.

PARTIAL LOSSES (10-20 bbl’s per hour):

Mix 12.5 lbs/bbl to 25 lbs/bbl of Ultra Seal® XP and spot across the thief zone. For high
permeability formations, add 25 lbs/bbl of Ultra Seal® C to 12.5 lbs/bbl of Ultra Seal XP® and
spot across the thief zone.

HEAVY LOSSES:

Mix 40 lbs/bbl of Ultra Seal® C and 20 lbs/bbl of Ultra Seal® XP in the slug tank. This pill
should be spotted above the thief zone and spotted out of the bit at slow pump rate.
If the above formulation is not successful, consider 40-60 lbs/bbl of Ultra Seal® Plus.
A minimum pill size of 50 barrels should be mixed and pumped.

TOTAL LOSSES:
Mix 40-60 lbs/bbl of Ultra Seal® Plus with the existing drilling fluid. A minimum of 100 barrels
of pill should be pumped and spotted across the loss zone. It is recommended to allow the pill
to soak for two hours before attempting to circulate.

Should the above methods fail to regain circulation, consider a Poly Plug® pill, see product
data sheets for more information.

Page: 14

Particle Size Distribution of Ultra Seal® XP

GILSON DRY SIEVE ANALYSIS
CHART REFLECTS % DRY PRODUCT RETAINED ON EACH RESPECTIVE SCREEN

Micron / Screen Size Wt. (10 gram sample) % (Cumulative)
+1905m / 10 mesh 0.0 0%
+279m / 50 mesh 0.34 4%
+178m / 80 mesh 0.42 8%
+140m / 100 mesh 0.46 12%
+74m / 200 mesh 3.19 45%
5.32 55% minus 200 mesh
-74m / - 200 mesh
Totals 9.73

Particle Size Distribution of Ultra Seal® TG


+1905m / 10 mesh 0.0 0%
+279m / 50 mesh 0.6 6%

+178m / 80 mesh 0.17 8%
+140m / 100 mesh 0.81 17%
+74m / 200 mesh 6.2 80%
1.97 20% minus 200 mesh
-74m / - 200 mesh
Totals 9.75%

Page: 15


Particle Size Distribution of Ultra Seal® C


+1905m / 10 mesh 0.11 1%
+279m / 50 mesh 2.87 30%
+178m / 80 mesh 0..82 39%
+140m / 100 mesh 0.56 45%
+74m / 200 mesh 2.55 71%
2.76 29% minus 200 mesh
-74m / - 200 mesh
Totals 9.67 100%

Particle Size Distribution of Ultra Seal® Plus


+1905m / 10 mesh 0.54 6%
+279m / 50 mesh 3.96 47%
+178m / 80 mesh 0.9 56%
+140m / 100 mesh 0.25 59%
+74m / 200 mesh 1.21 71%
2.75 29% minus 200 mesh
-74m / - 200 mesh
Totals 9.61% 100%

Page: 16


POLY PLUG®
P r o f e s s i o n a l F l u i d S e r v i c e s, L LC

AUGUST 2006
PRODUCT DESCRIPTION
Poly Plug® consists of a XLR® is required. in
pharmaceutical grade- Case Histories
Ultra Seal-XLD® is a
cross-linking agent, a silicone based de-foamer
blend of high molecular
and aids in reducing Deep Water 2
weight polymer and USA
viscosity. Other de-
Ultra Seal-Plus® , (a foamers should be pilot Sub Salt - 2
broad range of fibers to tested prior to use. Rubble
slow seepage of the poly-
Poly Plug® was
mer into the formation). Tuscaloosa 2
developed for high Trend
The cross-linking action is permeable formations. Oklahoma 3
a function of the loss zone targeted.
Poly Plug® has a high
temperature. For tem-
viscosity thus enabling
peratures below 100 Tuscaloosa 3
the polymer to stay with Trend
degrees F an accelerator,
Ultra Seal-XLA® is Tuscaloosa 3
required. For Trend
temperatures above 125
degrees F, a delaying Special points of
agent, Ultra Seal- interest:
• Time Controlled
• Robust Gel Chemistry
• Density controllable
with barite or hema-
tite

PRODUCT BENEFITS • Insensitive to H2S and
CO2
• Temperature stable up
to 400º F
Poly Plug® effectively seals Poly Plug® can be Poly Plug® is a single sack,
• Not intended for use in
fractured, vugular, weak, circulated around the BHA pre-blended product and is
the reservoir, product
flowing and over pressured without the risk of stuck designed for ease of use. should be considered
formations. pipe. Simply add one sack of permanent
Poly Plug® per 42 gallons
Poly Plug® can be pumped Poly Plug® develops
of water.
through the bit, mud minimal compressive
motors and MWD/LWD strength, eliminating the Poly Plug® is compatible
Page: 17
tools. risk of side track. with WBM and OBM.


Deep Water–Casing Shoe Estimated SAVINGS $700,000
After waiting 8 hours, the drill string
Drilled out 13 3/8” casing shoe and
was TIH and the Poly Plug pill was
could not obtain the desired shoe test.
tagged at 6,725’. Washing and reaming
A 100 bbl 13.3 ppg Poly Plug pill was
continued to a depth of 6749’ and the
blended. The pill was blended in the
drill string was then POOH to the
rig slugging tank and took 3 hours and
casing shoe. A FIT was performed to
45 minutes to build and weight up.
425 psi-, an EMW of 14.5 ppg.
(Note: Only a gun line available for
agitation, the Poly Plug was mixed Drilling Operations commenced with-
out incident. Money saved on rig time
through the rig hopper)
when compared to a cement squeeze
-The well was drilled to 6,749’ the drill
was $700,000.
string was POOH to 6,589’. 88 bbls of
OPERATOR: EL PASO
Poly Plug® was squeezed into the
formation. The well was left shut in for LOCATION: EWING BANKS
eight hours.
DRILLING FLUID: GYP WBM

Gulf of Mexico-Sub Salt (Rubble Zone)
A 100 bbl pill of Poly Plug® was mixed squeezed into the formation leaving 35 The well was left shut-in and the pill
in the slug tank and weighted to 17.0 bbls in the annulus. Shut-in pressure was waited on (8) hours. After (8)
ppg. The bit was placed 10’ above the was 300 psi on the casing and 150 psi hours circulation was established and
estimated loss zone. The pill was the drill string was staged in the hole.
on the drill pipe.
pumped to the bit with no returns. The plug was washed through and
After 15 bbls of Poly Plug® cleared the drilling commenced without further
bit, full returns were observed. losses.
OPERATOR: BHP AMERICAS
After evacuating the drill string of
“Loss Rate was over 100 BPH
Poly Plug®, the drill string was POOH
DRILLING FLUID: SOBM
static and 0ver 200 BPH dynamic”
to the casing shoe. The Hydril was
closed and 50 bbls of Poly Plug® was

South Louisiana-Tuscaloosa Trend (Deep & Hot)
All exposed sands were pay zones and loss zone before pressure limitations of
the well was loosing 25 BPH. 800 psi on the casing occurred. The OPERATOR: BP
Poly Plug pill was held in place for (1)
The Poly Plug pill was blended in a 40 DRILLING FLUID: 17.4 lb/gal OBM
hour and then a trip was made for a
bbl batch blender and took 1.5 hours
new bit. Operator was able to wash BHT: 380 DEGREES F
to build and weight up to 17.4 ppg.
and ream to bottom with no further
The pill was pumped down the drill losses and continue to drill without
pipe and after clearing the bit by (1) further incident.
bbl, the drill string was POOH to 100’
above the casing shoe (+/- 19,000’) and
a total of 8 bbls was squeezed into the

Page 18

Grady County, Oklahoma (Oil Sand Creek)
Lost complete returns @ 16714’ and mixed & spotted. After 120 bbls into
1000 bbls of OBM was lost while the displacement a trickle of returns
attempting to circulate. Mud weight were obtained increasing to 75-80%
was cut and LCM pills were spotted in once all the displacement fluid had
concentrations of 40-50 ppb. Another been pumped. The drill string was
POOH to 15,427’ and shut down.
700 bbls of OBM was lost.
After waiting 5 hours POOH to 7951’
The fluid level was checked with wire
and break circulation. Full returns were
line and was determined to be 800’. A
established at 7,951’. The drill string
60 bbl Poly Plug® pill was mixed and
was staged into the well bore to the
spotted. After 6 hours the annulus was
total depth of 16,714’ with full returns.
filled with 30 bbls of 11.8 ppg OBM
Drilling was completed to the depth of
with some seepage noted at 20 BPH.
16962’ with no further losses.
The drill string was TIH to 16273’ &
OPERATOR: MARATHON
attempted to circulate with no returns.
A second 60 bbl Poly Plug pill was
WELL: MITCHELL 2-34

South Louisiana-Tuscaloosa Trend (Deep & Hot)
The objective was to seal off existing the Poly Plug® into the perforations. shut in and the pill was allowed twelve
perforations in order to produce a Five bbl’s of Poly Plug was left above hours to develop maximum strength.
lower zone (TTPD). The total length of the perforations and the coil tubing was After waiting twelve hours the
POOH to 500’ above the estimated top remaining gel was circulated out the
the perforated interval was 90’.
of the Poly Plug® slurry. The well was well and the perforations tested. Upon
A total of 60 bbl’s of Poly Plug® and 5
a positive test the lower zone was
bbl’s of Ultra Spacer® was mixed and
perforated. The well has been on
pumped through 1 1/4” CT to a depth
production for over 2 years with a
“Successful Shut Off with a
of 21,051’. The well was on vacuum
12,600 psi differential across the upper
during the displacement and Ultra 12,600 psi Differential Pressure
perforations without any cross flow.
Spacer® was pumped ahead of the Poly and 380º F”
OPERATOR: BP
Plug® to prevent over displacement of
WELL: PARLANGE #8

South Louisiana-Tuscaloosa Trend (Deep&Hot)
The objective was to seal off existing waiting on the pill to develop is currently producing gas from a high
perforations in order to produce a maximum strength. After 8 hours the pressure zone below the shut off
pill was washed through with 1 1/4” CT
lower gas zone. The existing perforations without cross flow.
perforations had been producing large and a positive test achieved across the The differential pressure across the
amounts of coarse sand and a large perforated interval. A perforating upper (shut off) perforated interval is
carvernous zone was suspected behind assembly was picked up and TIH below 9,800 psi. The reservoir temperature
the 7-5/8” casing. With the well on the existing perforations to perforate across the upper perforated interval is
vacuum, 30 bbls of Poly Plug® was the target zone. 400ºF.
pumped to the EOT at 18,045’ and As of April 21, 2005, almost 1.5 years OPERATOR: BP
over displaced by 1 bbl. 200 psi over after the Poly Plug® treatment this well
initial SIP was held for 8 hours while WELL: DEBATAZ #8

Page 19

POLY PLUG® (CLEAR GEL)
P RO F E S S I O N A L F L U I D S E RV I C E S, L LC

AUGUST 2006

Case Histories

CHEMICAL 2
LINER

PRODUCT DESCRIPTION GRAVEL PACK 2
SHUT-OFF
POLY PLUG® (CLEAR GEL) is formulated with high concentrations of low
WATER SHUT- 2
molecular weight anionic polymer. When combined with a carboxylate
OFF
complex cross linking agent, the product produces a rubber like ringing gel
structure.
POLY PLUG® (CLEAR GEL) is also referred to as MARASEAL-EZSM.
MARASEAL-EZSM is exclusively licensed technology from MARATHON

PRODUCT BENEFITS
Special points of
POLY PLUG® (CLEAR GEL) is NEVER a drill-out problem. Simply wash interest:
through or dump bail any material left in the casing for easy clean out!!!
• Full shut off treat-
ments into rock
matrix less than
750 milli-darcies
POLY PLUG® (CLEAR GEL) is permeability of 5 to 750 md. POLY PLUG® (CLEAR GEL) is
• Effective in shutting
designed with a low viscos- POLY PLUG® (CLEAR GEL) is a mixed into fresh or salt off water or gas
ity prior to cross-linking to solids free fluid which works water at concentrations of
• Effective in sealing
aid in injectivity. up to 5%.
by entering the reservoir
casing leak
When placed in small and reducing permeability, Each POLY PLUG® (CLEAR
• Effective in sealing
openings such as pore not by plugging the GEL) treatment is based on
gravel pack
throats or small channels perforations as in Portland the bottom hole
behind casing, the result Cement treatments. temperature, casing size,
is total shut-off. POLY linear feet of perforations
PLUG® (CLEAR GEL) is and other variables.
designed for shut off
treatment into matrix

Page 20

Chemical Liner (Depleted Gas Zone) Lake Arthor, Louisiana
120 bbls of Poly Plug® (CLEAR GEL)
OBJECTIVE:
was squeezed into the depleted
Create a chemical liner across a
gas reservoir forming a chemical
depleted gas reservoir.
liner. Target penetration was
(14,000 psi Delta “P”)
based on 3.0’ radial penetration.
The well was drilled to 17,010’ with
The liner was run to bottom and
an 8-1/2” open hole. Difficulties
cemented without incident. Full
were encountered running the
circulation was observed during the
7-5/8” liner when it became
cement displacement with cement
hydraulically stuck and could not
tops to the required height. The
be run to bottom. The portion of
differential pressure across the
the liner which could not be pulled
depleted zone was 14,000 psi.
was milled. After milling operations
were complete, the hole was
reamed from 16,740’-16,950’ and
Operator: Noble Energy
opened to 9-1/2”. After hole
opening operations were complete, Well Name: Laurents #1

Water Shut Off (Gravel Pack) Ewing Banks, Gulf of Mexico
estimated to be in the order of sev- well head.
OBJECTIVE:
eral feet from the perforations.
Shut-off gravel pack completion from The well was then put in re-
After waiting twenty four hours, the
10,442’-10,466’ and complete / perfo- completion mode and perforated
remaining gel was removed via e-
rate from 13,886’-13,897’ below the existing perforations.
line bailer and the well was tested
The well is currently producing over
A fifty barrel treatment was bull to 2,500 psi or 1,000 psi over
480 barrels of oil.
headed down the tubing and dis-
“This was a proven success in gravel
placed with sea water. Four bar- Well Specifics:
pack shut off where conventional
rels of POLY PLUG® CLEAR GEL was
200-1,000 md permeability with
cement would have required a side
left above the gravel pack screen
31% porosity.
track. Furthermore, this application
to help prevent over displacement.
Gel invasion into the reservoir was proved POLY PLUG® CLEAR GEL could
Reservoir Temperature: 205ºF
be applied without the expense of a rig
or coil tubing.”

Water Shut-Off (Gravel Pack) Ewing Banks, Gulf of Mexico
accept the gel treatment. As well was pressured up to 1,000 psi
OBJECTIVE:
expected, the well immediately over well head and the perforation
Achieve a complete shut-off
went on vacuum. tested. A negative test to 400 psi
treatment from channels behind
was also applied to verify the shut
4 1/2” casing. The 45 barrel treatment was
off.
applied to the perforations.
A 45 barrel treatment designed for
Approximately one barrel of gel per This was a proven success in
maximum penetration into matrix
linear foot of perforations was formation shut off where
pore spaces. Prior to the
pumped. The well was left shut in conventional cement would have
application, an injection rate was
for twelve hours. The remaining required drill out.
established with water to determine
gel was washed through with via
the potential for the interval to Operator: Stone Energy
CT and high pressure nozzle. The
Well Name: OCS-G 7917 (A-8)

Page 21

ULTRA SQUEEZE®
P RO F E S S I O N A L F L U I D S E RV I C E S, L LC

AUGUST 2006
PRODUCT DESCRIPTION
Ultra Squeeze® Ultra Seal® XLD is a
consists of a silicone based de-
Case Histories
foamer and aids in
pharmaceutical
grade cross linking reducing viscosity.
agent, a blend of low Other defoamers OKLAHOMA 2
molecular weight should be pilot tested
polymer and a prior to use.
EAST TEXAS 2
filtration agent.
XCD polymer is
The cross linking required for
BC, CANADA 2
action is a function of suspension of the
temperature. For filtration agents and
temperatures below any weight material.
100 degrees F an
Ultra Squeeze® is
accelerator, Ultra
designed to produce
Seal® XLA is
both an open hole
required. For
plug and an inner
temperatures above
zonal shut off. The
125 degrees F, a
product is designed
delaying agent,
for matrix and
Ultra Seal® XLR is
Special points of in-
fractured formations.
required.
terest:
• Time Controlled
• Robust Gel Chemistry
• Density controllable with
barite or hematite
• Insensitive to H2S and CO2

PRODUCT BENEFITS • Temperature stable up to
400º F
• Not intended for use in the
reservoir, product should be
The slurry is pumped to about this product is the The inner zonal plug has
considered permanent
a vertically defined zone dewatered phase cross sufficient strength to
• Provides two plugs in one.
and a slight squeeze is links providing an inner prevent fluid intrusion
applied. When placed in zonal shutoff. The open into the well bore, even
a well bore, the slurry hole plug holds the under high differential
dewaters to form an polymer solution in place pressures after drilling
open hole plug while it cross links, out the open hole plug.
composed of filter aid forming a non flowing
Page 22
material. What is unique gel inside the formation.

Cement City, Oklahoma (Depleted Sand)
The second pill was squeezed as
WELL HISTORY
per the first pill scenario and the
Depleted Sandstone at 16,000’.
well was left shut in for 6 hours.
Well bore loss previous to Ultra
Squeeze® was 2,500 bbls of OBM. After tagging the second pill,
Three cement plugs were pumped bottoms up was circulated the
prior to Ultra Squeeze® and the drilling fluid conditioned. Washing
and reaming commenced, and
well bore was on vacuum.
drilling operations continued for
An 80 bbl Ultra Squeeze® pill was
another 800’ with no loses and the
blended and pumped from the
well was T.D.
casing shoe at 15,500’. After 8
hours the well was circulated with OPERATOR: CHEVRON
full returns. The Ultra Squeeze®
LOCATION: OKLAHOMA
pill was drilled through and returns
DRILLING FLUID: OBM
were noted to be approximately
70%. A second pill of 40 bbls was
blended.

East Texas (Fractured Limestone)
pulled above the slurry and the After squeezing a total of 8 bbls,
OBJECTIVE
Hydril closed. Slight hesitation the well stabilized with 200 psi on
Cure loss circulation into the Travis
squeezes were applied up to 250 the casing and was left shut in for
Peak (Fractured Limestone) and
psi. After squeezing 2-3 bbl (6) hours. The plug was washed
increase mud weight to safely drill
increments, the well was allowed to through and drilling fluid
through tectonically stressed shale
conditioned. The drill pipe was
stabilize.
formations.
POOH to the casing shoe and a
The well was experiencing dynamic “Inner Zonal Shut-Off Provided a FIT performed to 10.9 EMW. The
seepage losses of 30 bbls/hour. A well tested. The mud weight was
Chemical Liner, Increasing FIT
20 bbl pill of Ultra Squeeze® was increased from 10.1 to 10.7 and
Across the Travis Peak Formation
mixed and spotted across the drilling commenced without further
by 0.7 lb/gal”
target formation. The drill pipe was incident.

Fort Nelson, B.C., Canada (Fractured Sandstone)
Operator was drilling ahead with no With the drill pipe on vacuum, Ultra into the formation at 0.25 BPM.
losses when a drill break occurred Squeeze® was pumped into the The well was left shut in for (8)
and the bit fell 5’. Total loss of drill pipe. After +/- 140 bbls of hours. The pill was tagged below
circulation occurred into a fractured Ultra Squeeze® exited the bit, the casing shoe and washing and
sandstone. partial returns were be observed on reaming commenced.
The BHA was placed 5 barrels surface. Five barrels of Ultra
A successful FIT was obtained
inside the 13 3/8” casing and 180 Squeeze® was left in the drill pipe
and drilling commenced without
barrels of Ultra Squeeze® was to prevent contamination with OBM
further incident.
blended and formulated for a static while pulling above the pill.
OPEN HOLE SIZE: 12 1/4”
BHT of 122 degrees F. The Hydril was closed and 10 bbls
of Ultra Squeeze® was squeezed MUD TYPE: 80/20 OWR OBM

Page 23

ULTRA SPACER®
P r o f e s s i o n a l F l u i d S e r v i c e s, L LC

August 2006
PRODUCT DESCRIPTION
FORMATION Because of its fluid loss
properties, Ultra
DAMAGE & Loss
Spacer® aids in
CIRCULATION
reducing lost circulation
Special points of interest:
Prevention problems in fragile,
⇒ Reduces potential
unconsolidated, and
Ultra Spacer® works well
damage from filtrate
fractured formations.
in high permeability
invasion from of feet to
The polymeric fluid loss
formations or in
only inches.
additive reacts almost
formations with low
⇒ Provides excellent
immediately upon
fracture gradients.
compatibility with
contact with the
Because the seal formed
drilling fluids and
formation for quick
by Ultra Spacer® raises
cement.
results without filter
the formation’s fracture
⇒ Prevents fall back.
cake development.
pressure, cement can be
placed at casing depth ⇒ Improves Cement Bond.
For cases in which fluid
with higher equivalent loss can be total and ⇒ Density controllable, up
circulating densities severe, Ultra Seal® to 19.0 lb/gallon.
(ECDs) without Plus should be added to ⇒ Stable to 400º F
increasing the risk of the spacer to enhance
formation break down. fluid loss prevention.
This capability is highly surfactant, Ultra Surf™
Recommended
beneficial in wells in is recommended in
concentrations are 20 to
which a narrow margin concentrations of 0.5 to
40 pounds per barrel.
exists between the 2 gallons per barrel of
When used in oil base
fracture gradient and the water.
mud applications, a
mud density.

PRODUCT BENEFITS “95-100% RETURN
PERMEABILITY”

Forms a non invasive Improves ECD’s at inches.
seal to prevent filtrate casing depth in wells Ultra Spacer’s® low
invasion into the where fracture gradients rheology enhances
producing formation and mud weights limit removal of gelled drilling
(especially important in the density of cement. fluid from the hole for
high permeability wells or Reduces potential superior hole cleaning
when cementing in damage from filtrate performance.
formations with low invasion from feet to only
fracture gradients). Page 24

ULTRA SPACER®
What’s good for your well Ultra Spacer® gives you formation’s normal
bore is not always good for control over filtrate damage. permeability for optimum
an oil bearing formation. Ultra Spacer®, a specially production.
Filtrates from the cement formulated cement spacer
slurry can seriously damage based on unique invasion
a producing formation, prevention technology, forms
hindering production and a barrier along the surface of
increasing the need for the formation to shut out
stimulation. filtrates and preserve the

When a cement slurry is placed on top of
Filtrate from a cement slurry penetrates
Ultra Spacer®, no cement filtrate invasion
untreated dry, 20/40-mesh sand in less Ultra Spacer® penetrates untreated
nor additional invasion of Ultra Spacer® is
than 1 minute.* sand to a depth of 4 inches before
observed after 46 minutes.*
creating a seal.*

Field Results
⇒ Improved zonal isolation & excellent mud displacement are achieved

as indicated by bond logs and produced fluids.

⇒ Ultra Spacer® Prevents Fall Back of Cement Tops.

⇒ Provides Increased Well Productivity.

Page 25


CASE HISTORY SOUTH TEXAS - GAS WELL
Ultra Spacer® has been used in
seven wells in a South Texas
formation with exceptional results.
The following case history is
representative of the results
achieved for this operator.

Application:

An independent operator drilled a
directional wildcat well from a small
drilling pad surrounded by
wetlands. Because drilling from the
site was restricted to summer and
early fall, no time could be allotted
for remediation of cement seals
across the producing intervals. The
producing interval contained an
estimated 25 to 30 sands requiring
zonal isolation over a depth of
Results: The cementing treatment was successful and excellent
2,000 feet. The operator was
bonding and annular seal were achieved throughout the producing
concerned about the potential for
intervals. Bond logs indicated superior bonding and cement fill, and
lost circulation in the wells and did early production from the well exceeded expectations. The operator
not want to damage the sands has since drilled three additional wells using Ultra Spacer® in the
production cementing treatment.
since time was a critical factor in
these operations.
bonding was established over the entire cemented interval resulting in
quot;Good

water free completion…It was an important factor in the successful completion
of one of the largest discoveries in Southeast Texas in the last 50 years.quot;
– Ross Davis, President, Davis Bros. Oil Producers, Inc.

CASE HISTORY - OFFSHORE GULF OF MEXICO
Ultra Spacer® has been used in allow stable plug placement to pro-
two deep, offshore wells to prevent vide long term isolation. Because
lost circulation and allow more of damage to the formation sands,
efficient clean sweeping of holes. lost circulation was also a problem.

Application: An operator with Results: The use of Ultra Spacer®
deep, hot wells offshore Gulf of resulted in efficient clean sweeping
Mexico was experiencing problems of the hole, reduced lost circulation,
achieving efficient hole cleaning to and improved plug results.

Page 26

CASE HISTORY - COAL BED METHANE

Ultra Spacer® has been used in over forty wells in the Powder River Basin to eliminate cement fall back
and improve production. The following case history is representative of the results achieved in these
wells.

Application:

A major operator was experiencing fall back of cement tops after cementing production strings in coal bed meth-
ane (CBM) wells in the Powder River Bain. The wells were shallow (less than 2000 feet) and experienced signifi-
cant lost circulation during drilling and cementing operations. Low density drilling fluids and cements did not
completely solve the lost circulation problem. Fall back after cementing resulted in incomplete protection of the
casing, as well as introduction of cement slurry into the producing formation. Because production in CBM wells
is highly dependent on fracture networks in the coal, the loss of cement to the coal formation had a strong
potential for inhibiting production.

Solution:

Ultra Spacer® was used during the cementing of the production casing on five new wells to prevent cement fall
back and prevent formation damage to the fracture networks in the coal bed. The operator pumped 10 barrels of
Ultra Spacer® ahead of their standard, low density cement.

Results:

The use of Ultra Spacer® resulted in elimination of cement fall back, produced excellent bond logs, and
improved production.

CASE HISTORY - COAL BED METHANE
An operator (Amvest) in Osage The primary goal of this project
County, Oklahoma, has used Ultra was to reduce the lost circulation
Spacer® in 31 wells to reduce lost believed to damage the fracture
circulation and damage to the network in the coal bed leading to
fracture network. reduced productivity and to
determine Ultra Spacer’s® affect
on cementing, stimulation
Application:
treatments, and production.
Ultra Spacer® was pumped
directly ahead of cement or as a Results: This project has just been
stabilizing fluid introduced into the completed. Production results are
air drilled hole immediately after being analyzed and are not yet significantly lower and initial water
drilling. available. However, fracture production rates are higher in wells
initiation pressures have been in which Ultra Spacer® was not
used.

Page 27

To Order Call: 888-862-7177

RECENT ULTRA SPACER® CASE HISTORIES

BASS ENTERPRISES-STATE LEASE, INLAND BARGE

Well Location-Well Name: Pointalahache, Louisiana - VUB Morgan City #8
Open Hole Size: 12 1/4” Casing Size: 9 5/8”
Mud Weight: 12.4 lb/gal WBM Cement Density: 16.4 lb/gal
Ultra Spacer Volume: 55 bbl’s Ultra Spacer Density: 14.0 lb/gal

Objective: Solve loss circulation during cement displacement and maximize cement bond.

Post well Results: For the first time in this field, full returns were documented for the entire ce-
ment displacement.
Reference: Pat Blanchard - Drilling Superintendent PH# 504-836-7200

Well Location-Well Name: Pointalahache, Louisiana - VUB Morgan City #8
Open Hole Size: 6 3/4” Liner Size: 5 1/2”

Objective: Solve loss circulation during cement displacement and maximize cement bond.

Post well Results: full returns were documented for the entire cement displacement.
Reference: Pat Blanchard - Drilling Superintendent PH# 504-836-7200

Page 28


RECENT ULTRA SPACER CASE HISTORIES

BP-OKLAHOMA

Well Location/Name: Red Oak, Oklahoma - Harmon McFerran 7-34
Mud Weight: 10.5 lb/gal OBM Cement Density: 16.4 lb/gal
Objective:
Maximize cement bond, minimize formation damage from the filtrate of the cement slurry.

Post Well Results:
As indicated by a CBL, good isolation/cement bond resulted across the interval.
Reference: Louis Romo - Drilling Engineer Ph# 281-366-4632

Well Location/Name: Red Rock, Oklahoma - Myton #11
Mud Weight: Air Drilling Cement Density: 16.4 lb/gal
Objective:
Achieve good isolation/cement bond across a shallow fresh water aquifer at +/- 500’ and eliminate a
short string of casing which had been required in previous wells to isolate the aquifer.

Post Well Results:
Great hole cleaning along with good bonding resulted across the entire interval, including across the
fresh water aquifer. Substantial savings was realized by eliminating the short string of casing which
had been required in previous wells.
Reference: Roberto Pena - Drilling Engineer Ph# 281-366-7892

Page 29



CIMAREX-MAGNUM HUNTER / GULF OF MEXICO

Well Location/Well Name: Main Pass Block 185 - Well #1
Mud Weight: 15.8 lb/gal Cement Density: 17.0 lb/gal
Objective:
Reduce gas migration and casing pressure issues.

Post Well Results:
Due to the non invasive seal fluid migration into the formation from the cement slurry was prevented.
Gas migration issues were eliminated and zero casing pressure was observed after the cement job
which had never occurred in this field.
Reference: Clay Clary- Drilling Superintendent Ph# 801-270-3850

Well Location/Well Name: Main Pass Block 185 - Well #1
Open Hole Size: 6 3/4” Liner Size: 5 1/2”
Objective:
Reduce gas migration and loss circulation.

Post Well Results:
Gas migration was eliminated and full returns were observed during the entire cement displacement.

Page 30



Well Location/Well Name: West Cameron Block 295 - Well #3
Objective:
Mud/filter cake removal, reduce gas migration and reduce the risk of loss circulation during the
cement displacement.

Post Well Results:
Excellent mud cleaning/filter cake removal as observed at the flow line, the entire interval was
cemented without any incidence of loss circulation.

Well Location/Well Name: West Cameron Block 295 - Well #3
Objective:
Mud/filter cake removal, achieve good isolation and reduce the risk of loss circulation during
cement displacement.

Post Well Results:
The interval was cemented without any documented loss of circulation, the casing shoe was tested
to 18.4 lb/gal and the production interval is currently being drilled.

Page 31



Well Location: West Cameron Block 577
Objective:
Prevent micro annular gas migration due to the fluid loss from the cement slurry.

Post Well Results:
Due to the non invasive seal created across the interval, fluid loss from the cement slurry was re-
duced eliminating gas migration/casing pressure issues. The casing shoe was tested and drilling
operations commenced.

DAVIS PETROLEUM / TEXAS
Well Location: Harden County, Texas - Hampton Jenny #1
Objective:
Prevent loss circulation and maximize isolation across production sands.

Post Well Results:
The entire interval was cemented without loss circulation resulting in good isolation across the
production sands, as indicated by a CBL.

Page 32

Ultra Bond® Dump Bailer Cement Kit

Professional Fluid Services, LLC is pleased to announce its association with Thru Tubing
Systems (TTS) to provide product and service solutions for our wire line cement and resin
systems. TTS combines its thru-tubing tools and service experience with Professional Fluid
Services, LLC engineered cement and resin product to bring a system solution approach to
meeting needs and solving problems with this unique product line.

Proven Design Concepts

The Ultra Bond® Dump Bailer Kit provides everything you need to produce a cement slurry
designed for applications from 100 to 400º F. Designed features include:

Shear Bond to Casing - Maximum (Over 3 Times the Competition)
Down-Hole Seal to Gas - Excellent
Down-Hole Fluid Loss Control – Less Than 50 cc/30 Minutes API at 400º F
Down-Hole Strength Stability - Yes
Surface Mixability – Excellent
Surface Pumpability – Low Rheologies
Downhole Slurry Stability – Excellent
Thickening Time Control – 4 to 6 Hours at Down-Hole Conditions
Cement Density-17.0 lb/gallon
Strength Development – 500 PSI in 12 Hours, 2000 PSI in 24 Hours

The Ultra Bond® Dump Bailer Kit provides all these features without the problem of designing
and testing for each specific application. State of the Art admixture assures performance over a
wide range of temperatures and application conditions. The engineered approach that forms
the underlying foundation for the product ensures that it will perform predictably under a wide
application range.

Page 33


Ultra Bond® Dump Bailer Cement Kit “Continued”

Design Shear Bond Values

The Ultra Bond® Dump Bailer Kit has a higher Shear Bond Value of any system in the industry.
The higher the Shear Bond the higher the anchor strength the cement will produce and better
chance to seal and resist a pressure test. The Ultra Bond® Dump Bailer Kit is a combination of
several proprietary materials that produce the best shear bonds available. The following table
shows several examples of the Ultra Bond® Shear bond compared to two other competitor
products:

Relative Shear Bond and Anchor Strength

400
Shear Bond

300
200
200
280
100

0
Kit 1 Kit 2 Ultra Bond
Products Tested

Page 34


PROFESSIONAL FLUID SERVICES, LLC

Ultra Bond Kit vs HIP Kit

Prepared For: Donnie Burts
Date: 11 August, 2006

Prepared by: Paul Sonnier

CSI Technologies makes no representations or warranties, either expressed or implied, and specifically provides the
results of this report quot;as is” based upon the provided information.

Objective
A performance comparison between the High Shear Bond HIP Mix Kit supplied by HPI and the
Ultra Bond Kit supplied by M & D Industries was conducted at CSI Technologies.

Conclusions

Testing data demonstrates that the kits were comparable in most of the categories listed except
the Ultra Bond Kit’s shearbond was double the value obtained for the HIP Kit.

Test Data

HIP Kit: High Shear Bond HIP Mix Kit: P/N 980-201-01 mixed at 16.0 lb/gal with 230°F design.

Ultra Bond Kit: Ultra Bond Kit mixed at 17.0 lb/gal with 230°F design.

Tests Ultra Bond Kit HIP Kit
Measured 17.0 lb/gal 16.0 lb/gal
Density
Kit yield 5 gallons 4 gallons
Temp. Range 100°F – 300°F 175°F – 260°F
Testing performed at 230°F
Fluid Loss 40 mls 40 mls
Free Fluid 0% 0%
Rheology 80°F 190°F 80°F 190°F
300 rpm 600+ 600+ 580 490
200 rpm 460 448 426 370
100 rpm 270 266 268 224
60 rpm 178 180 190 168
30 rpm 100 106 116 104
6 rpm 26 30 36 34
3 rpm 14 18 20 20
Shearbond 439 psi 220 psi
Stability Stable Stable
50 psi 3:04 hrs:min 3:04 hrs:min
500 psi 4:06 hrs:min 3:56 hrs:min
12 hours 2012 psi 1624 psi
24 hours 2800 psi 2432 psi

CSI Technologies makes no representations or warranties, either expressed or implied, and specifically provides the
results of this report quot;as is” based upon the provided information.

Ultra Set® Activator Solution

System:
ULTRA SET® is a pre-flush of proprietary chemicals which provide the following benefits:
Water Wetting of Casing
Adhesive For the Cement
Catalyst For the Cement to Set Rapidly
Excellent Gas Blocking Properties

Slurry Density: 11.4 lb/gal
Kit Yield: 4.6 gallons per pail and will treat up to 23 Gallons of Ultra Bond®
Mix Requirement: Mix With a High Speed Mixer, Mix For (5) Minutes

Job Procedure:
1. Inspect the dump bailer for contamination of cement and or Ultra Set™ Activator.
2. Mix Ultra Set® Activator for (5) minutes prior to loading into the dump bailer.
3. Always use additional sand on top of a vented bridge plug. A minimum recommendation is
2’ of sand.
4. When dumping Ultra Set® Activator or the cement slurry, get as close to the dump depth, +/-
1’ if possible.
5. When dumping Ultra Set® Activator or the cement slurry, allow the product to drain for at
least 5 minutes prior to pulling out of the hole.
6. When pulling out of the hole, pull the length of one dump bailer in one minute, then pull as
fast as necessary.
7. Close the vent valve on the basket as easily as possible so as to not disturb the cement
bond to the casing.
Always allow the first dump of cement on top of the activator solution at least three hours
8.
before closing the vent valve. This should allow the cement enough time to get initial set and
prevent gas migration.
NOTE: Typical Job Runs/Dumps Follow:
1. Dump 2’ Sand on Top of TTVBP, POOH with Bailer.
2. Dump 4.5 gallons of Ultra Set® Activator on Sand, POOH with Bailer.
3. Dump up to 23 Gallons of Ultra Bond® cement slurry.
As Ultra Bond® Falls Through the Ultra Set® Activator, the Ultra Set® Activator is
Displaced up the Hole to Treat Additional Ultra Bond®, up to a Total of 22.5 Gallons
of Ultra Bond® Slurry.

Page 35


Ultra Set® Activator Solution

ULTRA SET® is a pre-flush of proprietary chemicals which provide the following benefits:

Water Wetting of Casing
Adhesive For the Cement
Catalyst For the Cement to Set Rapidly
Excellent Gas Blocking Properties
Setting Time/Compressive Strengths Comparisons (Table:1)
(See Mix Instruction for Ounces of Retarder Per BHT)

Slurry BHT ºF Initial Set (50 PSI) 500 PSI
Ultra Bond®+15.3 oz Retarder 300ºF 0 Hours:16 Minutes 3 Hours:23 Minutes
5% Ultra Set®
5% Ultra Set®
Ultra Bond®+1.7 oz Retarder 200ºF 8 Hours:0 Minutes 10 Hours: 0 Minutes
5% Ultra Set®
Ultra Bond® + 6.0 oz Retarder 211ºF 37 Hours:44 Minutes 41 Hours:8 Minutes

Shear Bond Effects
Conventional Cement - Class “H” at 500 psi Compressive Strength Will Yield the Following:
Perfect Condition/Casing Water Wet - 50 psi Shear Bond
Imperfect Condition/Oily Casing - 5 psi Shear Bond

Ultra Bond® Cement and Ultra Set® at 500 psi Compressive Strength Will Yield the Following:
Perfect Condition/Casing Water Wet - 150 psi Shear Bond
Imperfect Condition/Oily Casing - 75 psi Shear Bond

Page 36


PRO BOND™ Dump Bailer Cement Kit


Proven Design Concepts

The Pro Bond™ Dump Bailer Kit provides everything you need to produce a cement slurry
designed for applications from 100 to 300º F. Designed features include:

Shear Bond to Casing - Good
Down-Hole Seal to Gas - Good
Down-Hole Fluid Loss Control – Less Than 150 cc/30 Minutes API at 250ºF
Down-Hole Strength Stability - Yes
Surface Mixability – Good
Surface Pumpability – Low Rheologies
Downhole Slurry Stability – Good
Thickening Time Control – 4 to 6 Hours at Down-Hole Conditions
Cement Density-17.0 lb/gallon
Strength Development – 500 PSI in 12 Hours, 2000 PSI in 24 Hours

The Pro Bond™ Dump Bailer Kit provides all these features without the problem of designing
and testing for each specific application. State of the Art admixture assures performance over a
the underlying foundation for the product ensures that it will perform predictably under a wide
application range

Page 37


PRO BOND™ SSW (SATURATED SALT WATER)

PRODUCT DESCRIPTION
“Standard cement slurries have
the potential for a 2/3 reduction
in compressive strengths, shear
bond and ultimate compressive
Pro Bond™ SSW is a new addition to the Pro Bond™ product
strengths compared to
line of dump bailer cement kits. Pro Bond™ SSW is specifically
Pro Bond™ SSW when dumped
designed for dump bail placement into saturated NaCl brines.
into saturated NaCl brines”

The Pro Bond™ SSW dump bailer kit is designed for placement into a well which contains a
10 lb/gal NaCl brine. The kit has been formulated to minimize the effects of delayed
development of compressive strength’s by saturated NaCl brines.

Twelve hour compressive strengths for Pro Bond™ SSW at 350º F in a 10.0 lb/gal NaCl brine
are 1,342 psi. Most cement slurries would still have 0 psi compressive strengths after twelve
hours. The strength measurements were verified with a crush test performed on the set UCA
plug. Both Pro Bond™ SSW and competitive slurries were tested on a UCA at 14,000 psi and
356ºF.

·Designed for dump bailer application into saturated NaCl brines

·Formulated for bottom hole temperature from 300ºF-400ºF

·Twelve hour compressive strengths of 1,342 psi

·Six Hour thickening time

·Excellent Down Hole Stability


Page 38


ULTRA SEAL® S (SEALANT)

Professional Fluid Services, LLC and Thru Tubing Systems introduce the following Wire Line
kits for ULTRA SEAL® S which are designed for WATER SHUT-OFF via wire line operations.
ULTRA SEAL® S is a two part epoxy resin system. The final slurry volume after mixing Part “A”
with Part “B” is 5-Gallons. Three individual kits are available as per the various temperature
ranges.
ULTRA SEAL® S (KIT 1) Designed for BHT’s from 100˚F up to 160˚F

Special Properties (Patent Pending)
Very high compressive Strengths - Over 7,500 psi Ultimate Compressive Strength
Ultra-High Shear Bond Strengths - Over 1,650 psi
Low Rheologies
Excellent Pumpability/Dumpability
Excellent Gas Blocking Properties-Impermeable to Gas/Fluids
Exo-Thermic
Non Shrinking
Water Tolerant-Easily Falls Through Sea Water
Design Weight 10.0 lb/gallon (Can be weighted up to 18.5 lb/gallon-Upon Request)
Fluid Time of 5-7 Hours
Drill Out No Problem-Drillable at 12’ Per Hour

ULTRA SEAL® S (SEALANT) provides all these features without the problem of designing and
testing for each specific application. State of the Art admixtures assure performance over a
the underlying foundation for the product ensures that it will perform predictably under the wide
application range.


Page 39


LIQUID BRIDGE PLUG®

LIQUID BRIDGE PLUG® (RESIN) is a two part epoxy resin system designed for TTPB
applications. The final slurry volume after mixing Part “A” with Part “B” is 5-Gallons. Three
individual kits are available as per the various temperature ranges.

LIQUID BRIDGE PLUG® (KIT 1) Designed for BHT’s from 100˚F up to 160˚F

Special Properties (Patent Pending)
Very high compressive Strengths - Over 7,500 psi Ultimate Compressive Strength
Ultra-High Shear Bond Strengths - Over 1,650 psi
Low Rheologies
Excellent Pumpability/Dumpability
Excellent Gas Blocking Properties-Impermeable to Gas/Fluids
Exo-Thermic
Non Shrinking
Water Tolerant-Easily Falls Through Sea Water
Design Weight 12.0 lb/gallon (Can be weighted up to 18.5 lb/gallon-Upon Request)
Fluid Time of 5-7 Hours
Drill Out No Problem-Drillable at 12’ Per Hour

LIQUID BRIDGE PLUG® (RESIN) provides all these features without the problem of designing and
testing for each specific application. State of the Art admixtures assure performance over a
the underlying foundation for the product ensures that it will perform predictably under the wide
application range.


Page 40

PFS Brochure

Recomendados

Recomendados

Mais conteúdo relacionado

Mais procurados

Mais procurados (20)

Semelhante a PFS Brochure

Semelhante a PFS Brochure (20)

Último

Último (20)

PFS Brochure