Note: Descriptions are shown in the official language in which they were submitted.
1
HIGH-PERFORMANCE SEAWATER-BASED POLYMERIC FLUID FOR DRILLING OF
RESERVOIRS WITH TOTAL OR PARTIAL LOSS OF CIRCULATION AND HIGHLY
REACTIVE CLAYS, AND PROCESS FOR FORMING THE HIGH-PERFORMANCE
SEAWATER-BASED POLYMERIC FLUID ON-SITE
TECHNICAL FIELD OF THE INVENTION
The fluid and process of this invention relate to the technical field of
hydrocarbon reservoir drilling.
Typical oil wells with total or partial loss of circulation, of formations
with highly reactive clays or clay
intervals, in which a drilling fluid is applied to ensure safe and successful
drilling. Drilling of offshore
and onshore hydrocarbon reservoirs for fractured pore stages. Primarily, but
not limited to drilling
reservoirs in the Upper Cretaceous Tertiary Paleocene Breccia (UCTB), Upper
Cretaceous Breccia
(UCB) and Upper Paleocene Limestone Body (UCPB) producing fields.
This type of drilling requires greater expertise due to the conditions to be
faced, temperature, pressure
and circulation loss, stages of well fractures, swelling and dispersion of
shales, which can denature and
degrade the seawater-based drilling fluids. Generate complicated operations
such as stuck bits, stuck
pipes, well instability, formation damage, etc., thus representing a very high
investment cost for the
drilling of the reservoir and hydrocarbon production, and particularly an
increased risk to operating
personnel.
Date Recue/Date Received 2022-03-22
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BACKGROUND OF THE INVENTION
Drilling oil wells with total or partial loss of circulation will occur in few
places in the world. The
complexity of this phenomenon lies in the fact that the drilling fluid does
not return to the surface with
the formation cuttings, that is, the drilling fluid will not circulate with
the rocks from the cuttings to the
surface up to the solids control equipment, so the certainty of cleaning the
well is minimal or null.
Another problem is that the drilling fluid permeates the formation pore
resulting in total, partial or
intermittent losses.
An adequate design of the system to be used for oilfield drilling is of utmost
importance in order to
increase hydrocarbon extraction. A competent choice will allow a reduction of
drilling costs, a safe
operation for the personnel and a shortening of drilling times, together with
the resulting indirect
expenses.
The main challenge is the drilling of the Upper Cretaceous Tertiary Paleocene
Breccia (UCTB)
producing fields, in its stratigraphy, it consists of naturally fractured
limestones where total circulation
losses are present, complicating the unit operations that arise during the
drilling of the reservoir.
A secondary challenge is the swelling and dispersion of clays, so that unless
the clay intervals are
controlled the hole enters into unstable conditions, causing the loss of
chemical and mechanical stability
of the formation, increasing the risks of collapse, increased hydrostatic
pressure, trapping of the string
and therefore risky operation for personnel, etc.
The problems generated by the condition of total, intermittent and/or partial
loss of circulation are as
follows:
a) Uncertainty in hole cleaning. There is currently no fluid and/or
application process that can
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predict well behavior under this condition.
b) Logistic problems. Given the typification of these wells, it is necessary
to generate a large
quantity of drilling fluid to avoid the total loss of circulation during the
operation already started,
weighted as 1600 m3/day, which is significant due to the large movement of
materials in drilling
fluid vessels, causing the breakage of the continuous operation and increasing
the cost of the
well and non-productive times while waiting for the arrival of the materials.
c) String entrapment, caused by uncertainty hole cleaning and lack of
continuous operation.
d) High operating times. Since it is necessary to use a large volume of
drilling fluid, the vessels are
not enough to supply the drilling fluid and its generation. Only one or two
wells can be drilled
simultaneously due to total or partial loss of circulation, and the drilling
of more wells is not
possible.
Currently, the reservoir stage is drilled with seawater-based fluids, referred
to in Petroleos Mexicanos
by a generic name for all the fluids of different companies as BAMIL, which do
not meet the technical
and operational requirements and have an enormous variety among them.
The fluid of the invention is intended to provide advantages such as:
i Not requiring service vessels known as dilling fluid vessels for its
supply and generation.
ii The fluid can be formed from a process onboard platforms and
stationary equipment.
iii Allows drilling to continue, despite bad weather conditions.
iv Ensures operational continuity by reducing string entrapment due to
differential pressure and
packing.
v The drilling stage of the reservoir is significantly reduced by
days.
vi The torque-drag and hole-cleaning conditions versus the low-density (diesel-
based) fluid used
are considerably improved.
vii Allows drilling several reservoirs simultaneously, due to the ease of
supply.
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viii Provides efficient clay inhibitor in its chemical components to prevent
swelling and dispersion
of clays.
ix Provides a reservoir drilling fluid with lower environmental impact,
mitigable and biodegradable
in considerable time, by using seawater and its chemical components with low
or no corrosivity,
reactivity, explosivity, toxicity (with a lethal dose 50, DL50 determined and
safe), flammability,
biological-infectious that validates a safe operation versus a low density
drilling fluid (diesel-
based preparations) or other seawater-based fluids with solid or mixed
additives.
In the seawater-based polymeric fluid of the present invention, all its
components are in liquid state and
in suspension, generating a high-performance polymeric fluid in liquid phase,
with a feasible preparation,
fast homogenization, and safe for the operator-technician.
Applying a seawater-based polymeric fluid without solids confers a high-
performance by reducing and
improving the operation time, a vital resource in reservoirs with total or
partial loss of circulation. It
avoids formation damage, prevents and reduces mechanical accidents, reduces
investment costs and
operating expenses such as equipment and machinery rental, logistics, deferred
production, and fluid
loss.
The high-performance seawater-based polymeric fluid for drilling hydrocarbon
reservoirs with total or
.. partial loss of circulation of types 1 and 2 solves the following:
a) Fast generation fluid, as it is a fast preparation fluid due to its liquid
nature, that is mixed in the
equipment dams, and homogenized in a short and efficient time. This avoids
operational
stoppage to generate the fluid. Although there is a total loss of this
drilling fluid, the preparation
of the fluid is fast, which also allows continuous operation.
b) Optimized logistics of materials: by having liquid and suspended
components, the supply of
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these materials to generate this fluid is more agile, since any ship, not
necessarily a drilling fluid
vessel, can transport them.
c) Simultaneous drilling of several wells with drilling loss, without the
use of drilling fluid vessels,
supplied by other types of ships and in containers; its preparation and
operating time is short,
facilitating the simultaneous drilling of a large number of wells with this
condition while
allowing to handle the containers.
d) No formation damages: due to the low solids concentration of the fluid,
there is no damage to
producing formations and the remnants of the easy polymeric fluid can be
cleaned out of the
equipment with 15% HC1.
e) High efficiency of gas control in the formation: the formulation of the
present invention contains
a clay encapsulating additive, which acts as a gas controller, encapsulating
the gas and keeping
it controlled, as well as controlling the pressure during the drilling of the
well with total loss of
circulation.
0 Excellent rock-fluid interaction behavior: this polymeric fluid system
contains high efficiency
clay inhibitors. In formations with clay intervals, it helps to keep the hole
in stable conditions,
avoiding the swelling and dispersion of shales and, therefore, improves the
chemical and
mechanical stability of the formation, reducing the risk of string entrapment.
g) Torque and drag reduction: the high-performance seawater-based polymeric
fluid has an
excellent lubricity coefficient due to its physicochemical properties, helping
to reduce torque
and drag.
h) The pH condition of 9 to 11 allows the fluid not to be degraded by
bacteria.
i) This fluid confers rheological and thixotropic properties to the system. It
has excellent
rheological properties that ensure wellbore cleanliness during drilling. The
thixotropic property
helps keep cuttings in suspension during connections.
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Wells constructed in reservoirs with total loss of circulation. The design of
drilling fluid phases ranges
from bentonite drilling fluid, salt bentonite drilling fluids, reverse
emulsion drilling fluids and low
density drilling fluid (diesel or brine based) or, in the best case, seawater
based drilling fluid. Nowadays,
seawater-based drilling fluids are being used instead of diesel-based drilling
fluids for this last phase.
The operations are done by pumping this drilling slurry to the different zones
of the well. The most
critical zones are in the 8 1/2" and 6 1/2" bit stage with exposure and risk
of pipe sticking, string
entrapment, high temperature and critical pressure conditions.
Currently, there are several types of seawater-based drilling fluids on the
market. They can be
differentiated with respect to the fluid of the invention. Some of them are
made by companies such as
Schlumberger, MI-SWACO', Weatherford, for example, present problems of string
entrapment from
3025 m, the rheological and thixotropic properties of the fluid are inferior
according to the operational
need and loss of the original hole. A fluid by Baker Hughes presents string
entrapment problems from
2,979 m and above. Mogel's MOSW fluid, applied to the wells, presents
operational problems, suspends
drilling due to lack of chemical material, has clogging of screens in the
pumps due to lack of
homogenization, difficulty in maintaining the fluid viscosity making it
difficult to clean the well due to
chemical material out of specifications; exceeds the drilling days with a low
ROP, high slurry
consumption due to loss of circulation and requires the use of a support
vessel.
A fluid from the TIFP company provides an optimal fluid for drilling the Upper
Cretaceous Paleocene
.. Tertiary Breccia (UCPTB), Upper Cretaceous Breccia (UCB) and Upper
Paleocene Limestone Body
(UCPB) formations. It comprises five chemical components, is currently in use,
and differs from the
present fluid in that the fluid of the present invention uses from three to
five products, depending on the
case of field drilling. In the fluid by the TIFP company, all five necessarily
have to be used for any field
drilling.
Date Recue/Date Received 2022-03-22
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The high-performance polymeric fluid preparation process ensures compliance
with technical, safety and
time parameters. It avoids lumps of mixing solids that severely affects fluid
compliance by clogging
strainers, fluid pumps, piping, and/or motors, which would later require
cleaning bumps.
The fluid of this invention aims to provide a capable and high-performance
water based polymeric fluid,
where in an operative way it is not possible to use plugging materials to
mitigate the total, partial or
intermittent loss of circulation, that does not interfere in the cleaning of
the well or in excessive
preparations of cleaning bumps. This avoids damaging the formation, thereby
hindering the completion
of the well and therefore the production of hydrocarbons. It presents a
lubricity similar to low density
fluids (diesel base or brines).
A further objective to the present invention is to equip a process to easily
form high-performance
seawater based polymeric fluid, homogenized in all its chemical constituents
whose mixture is stable,
with maximum suspension and cuttings carrying capacity, inhibition and
dispersion of clays, and thermal
stability. Thereby solving the technical and cost problems of drilling
reservoirs with total, partial or
intermittent loss of circulation for fractured pore stages. Guaranteeing the
programmed stock of the fluid
from the beginning of the stage of any well to the reservoir. Being made from
high-performance and fast
mixing components that avoid plugging problems.
Date Recue/Date Received 2022-03-22
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DESCRIPTION OF THE INVENTION
Brief description of the figures
Figure 1 is a representation of the fluid application of the present
invention, avoiding the condition of
total or partial loss of fluid (red arrows), where (A) Fluid level 1200 mD
(measured depth), (B) Density:
0.40 g/cm3, Density of the fluid or slurry: 1.03 g/cm3.
Figure 2 shows the geometry of a type 1 well with loss of circulation, where
the reservoir stage is drilled
with a bit (BNA) of 8 1/2 " (in) with a density of 1.03 g/cm3 and operation at
a temperature of 125 C
with a horizontal displacement of 1023 m.
Figure 3 shows the geometry of a type 2 well with loss of circulation, where
the reservoir stage is drilled
with a 10 5/8" (in) bit (BNA) with a density of 1.03 g/cm3 and operation at a
temperature of 125 C with
a displacement of 312 m.
Figure 4 is a graph of the drilling of a reservoir type 2 well with loss of
circulation, with BNA of 10 5/8"
(in) with a density of 1.03 g/cm3 and operation at temperature of 125 C, (A)
Directional trajectory with
a maximum angle of 40 to 55 C, with a maximum DL of 2.5 /30 m.
Figure 5 is a graph of the drilling of a reservoir type 2 well with loss of
circulation, with BNA of 10 5/8"
(in) with a density of 1.03 g/cm3 and operation at a temperature of 125 C,
drilling 900 to 1000 mD with
intermittent loss of circulation (partial-total), drilling Upper Paleocene
(PS), Middle Cretaceous (MC),
Lower Cretaceous (1(1), Upper Jurassic Titonian (JUT) and Upper Jurassic
Kimmeridian (UJK).
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Figure 6 is a graph of the Balam 99 well; the drilling of the reservoir in the
10 5/8" (in) ANB stage was
programmed to 32 days. It was drilled to 1253 mD (interval 3112 to 4365 mD) in
10 days, with no
operational problems due to the application of the high-performance seawater
based polymeric fluid.
Figure 7 is a graph showing the average operating times of the reservoir
drilling stages (bars on the left)
and non-productive times (NPTS) (bars on the right), of the reservoir stage
with production casing pipe
run for the period from 2012 10 2018 of the Ku-Maloob-Zaap Asset drilled with
solid additive seawater
base fluids and low density fluids from 2012 to 2015 versus liquid additive
seawater base fluids from
2016 to 2018 (PEMEX, 2018). For the period 2016 to 2018, it can be observed
how it drastically
improves the average drilling days of the reservoir, decreases non-productive
days and eliminates trapped
strings.
Figure 8 is a graph showing the cation exchange capacity of Lower Paleocene
(IP) and Upper Cretaceous
Breccia (UCB) that was stabilized and inhibited by the high-performance
seawater-based polymeric fluid
of the Ayatsil 261 well, in the 6 1/2 " (in) drilling stage in the interval
from 4033 to 4281 m, density 1.03
g/cm3. In 4033, there is a total loss of circulation, so, in the interval from
4127 to the total depth of 4281
m, viscous pumping bumps were performed of 1.03 g/cm3 x 500 s, every 5 m
drilled, managing to drill
without problems the Upper Cretaceous Breccia (UCB). In the trips from the
well to the 7 5/8" (in) line
shoe at 4033 m, there were no drags or resistances. The lithology compendium
data from the Ayatsil 261
well during drilling of the reservoir is attached. Note that the formations
drilled showed low reactivity
with a maximum chemical exchange value of 7 meq/100 g of clay, attenuated by
the chemical inhibition
of the high-performance seawater-based polymeric fluid of this invention.
Figure 9 is a graph depicting the process of preparing high-performance
seawater-based polymeric fluid
on-site for total loss circulation reservoirs with highly reactive clays
typified for Middle Cretaceous
Date Recue/Date Received 2022-03-22
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(MC), Upper Cretaceous Paleocene Tertiary Breccia (UCPTB) and Upper Cretaceous
Breccia (UCB)
with operational temperature conditions of 80 to 120 C, where (T) is a weir
or mixing tank, (A) is a
deep well suction and discharge pump, (B) diaphragm pump for suction and
discharge of the products to
the mixing weir, (C) variable speed metal slurry pump connecting to the stand
pipe (E), (D) 275 gpm
centrifugal fluid mixing pump connected to an air compressor, (F) the
reservoir to be drilled, (1) first
product to be added, (2) second product to be added, (3) and finally, the
third product to be added to the
mixing weir.
Figure 10 is a graph showing the process of preparing high-performance
seawater-based polymeric fluid
on-site for total loss of circulation reservoirs with highly reactive clays
for Upper Paleocene Calcareous
Body (UPCB) with operating temperature conditions of 80 to 100 C, where (T)
is a mixing weir or tank,
(A) is a deep well suction and discharge pump that pumps the seawater, (B)
diaphragm pump for suction
and discharge of the products to the mixing weir, (C) variable speed metal
slurry pump connecting to the
stand pipe (E), (D) 275 gpm centrifugal fluid mixing pump connected to an air
compressor, (F) the
reservoir to be drilled, (1) first product to be added, (2) second product to
be added, (3) third product to
be added, (4) fourth product to be added and finally, (5) fifth product to be
added to the mixing weir.
Figure 11 is a graph showing the process of preparing high-performance
seawater-based polymeric fluid
on-site for total loss of circulation reservoirs with highly reactive clays
for Upper Jurassic Titonian (JUT)
and Upper Jurassic Kimmeridian (UJK) with high operational temperature
conditions of 120 to 170 C,
where (T) is a mixing weir or tank, (A) is a deep well suction and discharge
pump that pumps seawater,
(B) diaphragm pump for suction and discharge of the products to the mixing
weir, (C) variable speed
metal slurry pump connecting to the stand pipe (E), (D) 275 gpm centrifugal
fluid mixing pump
connected to an air compressor, (F) the reservoir to be drilled, (1) first
product to be added, (2) second
product to be added, (3) third product to be added, (4) fourth product to be
added and finally, (5) fifth
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product to be added to the mixing weir.
Figure 12 shows the results of the determination of rheological and
thixotropic properties of the high-
performance seawater-based polymeric fluid stabilized at 65 C, contaminated
with CO2, and with
temperature conditions of 120 C.
Figure 13 shows the results of the cation exchange capacity for the Ku-Maloob-
Zaap field of 23 meq/100
g and the Ayatsil field of 29 meq/100 g.
Figure 14 shows the result of the determination of the linear swelling where
the height of the tablet is
20. 3% in 20 hours
Figure 15 shows a graph of the linear swelling percentage behavior for the
high-performance seawater-
based polymeric fluid.
Figure 16 shows the results of the dispersion test of the pellet output and
drying of the pellet.
Figure 17 shows the accretion test results, with an accretion of 0.33 % for
the seawater-based polymeric
fluid.
Figure 18 shows the torque results with a load of 172.5 Kg/cm, at intervals of
0, 1, 2, 3, and 4 minutes,
the average, and a correction factor for the high-performance seawater based
polymeric fluid. The
reading for seawater should be between 34 + 4, so the correction factor is
1.01.
Figure 19 shows the solubility in 15% HC1, an acid used in the cleaning of the
drilling system. It is a
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seawater-based polymeric fluid soluble in 15% HC1, compatible with the
cleaning of the system.
Detailed description of the invention
According to the figures presented, the present invention refers to a high-
performance seawater-based
polymeric fluid for drilling reservoirs with total, partial, and/or
intermittent loss of circulation with
presence of highly reactive clays. Likewise, it refers to the process for
obtaining the high-performance
seawater based polymeric fluid on-site, formed and homogenized in the shortest
possible operation time.
Once the product is obtained, the application of the formed high-performance
seawater based polymeric
fluid is carried out for the drilling of reservoirs with loss of circulation
with highly reactive clays.
Formulation of seawater-based polymeric fluid systems for reservoirs with
total or partial loss of
circulation with highly reactive clays.
The fluid of the present invention is characterized in that the chemical
products that compose it are
liquids and, in suspension, elements that interact with each other giving the
fluid electrochemical affinity,
with lubricity, which meets rheological-tixotropic properties, viscosity,
inhibition and dispersion of
clays. Packaged in one cubic meter containers, for easy transportation and
operational handling. Prepared
and homogenized in short times. This fluid has the particularity that,
depending on the typification of the
field, the concentration to be applied and quantity of chemical products to be
used, ranging from three
to five, are designed, with an infinite and non-limiting possibility of
application to each of the fields with
existing reservoirs with total loss of circulation with highly reactive clays.
In the case of drilling total loss of circulation reservoirs with highly
reactive clays typified for Middle
Cretaceous (MC), Upper Cretaceous Paleocene Tertiary Breccia (UCPTB) and Upper
Cretaceous
Breccia (UCB) with operational temperature conditions from 80 to 120 C, the
design quantity of
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chemicals to form one cubic meter of the seawater-based polymeric fluid system
is characterized by
three products and the continuous phase. The first product, viscosifying and
suspension filtrate reducer,
consists of a mixture of polyanionic cellulose polymer and extracellular
polysaccharide suspended in
mineral oil, in an application concentration range of 9 to 15 Um'. The second
product is a liquid clay
inhibitor, consisting of a mixture of potassium chloride, choline chloride,
and heavy glycol in water, in
an application concentration range of 30 to 100 L/m3. The third product is a
liquid alkalinizer, consisting
of a monoethanolamine in deionized water, in an application concentration
range of 5 to 10 Um'.
Seawater, aqueous or continuous phase, part of the available component, is
used in an application
concentration range of 875 to 956 Um'.
In another case of total loss of circulation reservoir drilling with highly
reactive clays typified for Upper
Paleocene Calcareous Body (UPCB) with operating temperature conditions of 80
to 100 C, the design
of quantity of chemicals to form one cubic meter of seawater-based polymeric
fluid system is
characterized by five products and the continuous phase. The first product,
viscosifier and suspension
filtrate reducer, consists of a mixture of polyanionic cellulose polymer and
extracellular polysaccharide
suspended in mineral oil, in an application concentration range of 9 to 15
Um'. The second product is a
liquid clay inhibitor, consisting of a mixture of potassium chloride, choline
chloride, and heavy glycol
in water, in an application concentration range of 30 to 100 Um'. The third
product is a liquid alkalizer,
consisting of monoethanolamine in deionized water, in an application
concentration range of 5 to 10
Um'. The fourth product is a stabilizer and encapsulator of clays in
suspension, consisting of a mixture
of polyacrylamide and calcium carbonate suspended in mineral oil, in an
application concentration range
of 4 to 10 Um'. The fifth product is a liquid reinforcement inhibitor for
inhibiting clays, consisting of a
mixture of potassium chloride, magnesium chloride and glycol in water.
Seawater, aqueous or continuous phase, part of the available component is used
in an application
concentration range of 765 to 902 Um'.
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An additional case of total loss of circulation reservoir drilling with highly
reactive clays typified for
Upper Jurassic Titonian (JUT) and Upper Jurassic Kimmeridian (UJK) with high
operational
temperature conditions of 120 to 170 C, the design quantity of chemicals to
form one cubic meter of
seawater-based polymeric fluid system is characterized by five products and
the continuous phase. The
.. first product is a viscosifier and rheological stabilizer in suspension for
high temperatures, which consists
of a mixture of extracellular polysaccharide, cellulose-polyanionic polymer
and potassium chloride
suspended in mineral oil, in an application concentration range of 9 to 14
Um'. The second product is a
thermal stabilizer in suspension, consisting of a suspension of sulfated
acrylic polymeric acrylic in
mineral oil, in an application concentration range of 5 to 8 Um'. The third
product is a high temperature
filtration reducer in suspension, consisting of a suspension of acrylate
copolymer in mineral oil, in an
application concentration range of 6 to 9 Um'. The fourth product is a liquid
clay inhibitor, consisting
of a mixture of potassium chloride, choline chloride and heavy glycol in
water, in an application
concentration range of 30 to 100 Um'. The fifth product is a liquid alkalizer,
consisting of
monoethanolamine in deionized water, in an application concentration range of
5 to 10 Um'. Seawater,
aqueous or continuous phase, part of the available component is used in an
application concentration
range of 859 to 945 Um'.
The clay inhibitor, one of the components present in this high-performance
seawater-based polymeric
fluid, is efficient, allowing it to have better chemical and mechanical
stability of the formation and reduce
the risk of string entrapment by packing or differential pressure. It supports
the resolution of swelling
and dispersion of clays, which solves the problems presented by the current
drilling of oil fields with
total loss of circulation in the presence of highly reactive clays.
The following tables summarize the design of the high-performance seawater-
based drilling fluid for
classifying reservoirs with loss of circulation control with highly reactive
clays.
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The following table presents the function and concentration of each liquid
and/or suspended chemical
that homogeneously makes up a cubic meter of the seawater-based polymeric
fluid for total loss of
circulation reservoirs with highly reactive clays, typified for Middle
Cretaceous (MC), Upper Cretaceous
Paleocene Tertiary Breccia (UCPTB) and Upper Cretaceous Breccia (UCB) with
operational
temperature conditions from 80 to 120 C:
Product Function Concentration [Una
Seawater Continuous phase 875 to 956
Blend of polyanionic cellulose
polymer and extracellular Viscosifier and suspension
9 to 15
polysaccharide suspended in filtrate reducer
mineral oil.
Mixture of potassium chloride,
choline chloride and heavy Liquid clay inhibitor 30 to 100
glycol in water.
Monoethanolamine in deionized
Liquid alkalinizer 5 to 10
water.
The following table presents the function and concentration of each liquid
and/or in suspension chemical
product that homogeneously makes up a cubic meter of the polymeric seawater-
base fluid for total loss
of circulation reservoirs with highly reactive clays, typified for Upper
Paleocene Calcareous Body
(UPCB) with operating temperature conditions of 80 to 100 C:
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Product Function Concentration
[L/m3].
Seawater Continuous phase 765 to
902
Blend of polyanionic cellulose
polymer and extracellular Viscosifier and suspension
9 to 15
polysaccharide suspended in filtrate reducer
mineral oil.
Mixture of potassium chloride,
choline chloride and heavy Liquid clay inhibitor 30 to
100
glycol in water.
Monoethanolamine in deionized
Liquid alkalinizer 5 to 10
water.
Mixture of polyacrylamide and
Stabilizer and encapsulator of
calcium carbonate suspended in 4 to 10
clays in suspension
mineral oil.
Mixture of potassium chloride
' Liquid reinforcing inhibitor to
magnesium chloride and glycol 50 to
100
inhibit clays
in water.
The following table presents the function and concentration of each liquid
and/or in suspension chemical
product that homogeneously makes up a cubic meter of the polymeric seawater-
base fluid for total loss
of circulation reservoirs with highly reactive clays, typified for Upper
Jurassic Titonian (JUT) and Upper
Jurassic Kimmeridian (UJK) with high operational temperature conditions of 120
to 170 C:
Product Function Concentration
IL/m3].
Seawater Continuous phase 859 to
945
Mixture of extracellular
polysaccharide, cellulose Viscosifier and rheological
polyanionic polymer, and stabilizer in suspension for high 9 to 14
potassium chloride suspended temperature.
in mineral oil.
Sulfated acrylic polymer Thermal stabilizer in
5 to 8
suspension in mineral oil. suspension
Suspension of acrylate Filtering reducer for high
6 to 9
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copolymer in mineral oil. temperature in suspension
Mixture of potassium chloride,
choline chloride and heavy Liquid clay inhibitor 30 to 100
glycol in water.
Monoethanolamine in deionized
Liquid alkalinizer 5 to 10
water.
Each of the elements listed above in the formulation of the seawater-based
polymeric fluid of this
invention has the property of mixing and homogenizing in the shortest time
according to the order of
addition that has been listed, such that they will interact with each other
and without adverse reaction
with the continuous phase. By being completed in this manner, it makes it
possible for no phase to be
available for dispersion and interaction with the formation, and specifically
with the reactive clays
present in the various intervals.
Process for forming seawater-based polymeric fluid systems for reservoirs with
total or partial loss
of circulation with highly reactive clays on-site.
The process for forming a high-performance seawater-based polymeric fluid has
operational
characteristics according to the amount of fluid needed to drill a typical
reservoir. The fluid preparation
bumps depend on the operational volume; in general, for the equipment that
currently exists, mixing
dams with capacities range from 45 m3 to 120 m3 (Figures 9, 10, and 11, letter
T).
The present process is designed in that order of addition of the liquid
products or products in suspension
of origin, for the elimination of the polymer lumps, colloquially called fish
eyes, with the purpose of
improving the efficiency and reducing the time of incorporation between
products, obtaining a
significantly fast homogenization and mixing, diminishing or nullifying the
clogging of the sieves and
Date Recue/Date Received 2022-03-22
18
the damages to the pumping equipment.
The problem of a quick preparation of a seawater-based polymeric fluid on-site
and reducing the
agitation, dilution and homogenization times of the products with this
invention, which is not the case
for current seawater-based polymeric fluids, is solved by each product that is
added arriving in a mixture
or dilution each product, in liquid state and in suspension, thereby allowing
the simple handling and
immediate incorporation when adding the product according to the well
typification and the necessary
concentrations.
Before starting the process of forming the seawater-based polymeric fluid
systems, the following is
considered:
A) The design and particular requirements of each reservoir with total loss of
circulation are taken
into account.
B) The cleaning of the slurry mixing dams (Figure 9, 10 and 11, letter T) with
their instrumentation
equipment verified and in use.
C) Safety check of operating personnel.
D) The structuring and conditioning of the quantity of products to be used,
derived from taking into
account the drilling design of the reservoir.
E) The displacement of the chemicals that make up the seawater-based polymeric
fluid from the
port to the drilling site by ship and easy handling for its preparation.
F) Preparation of the fluid system on site.
G) Verification and inspection of the high-performance seawater based
polymeric fluid system, of
the quality and parameters to be met for the drilling of the formation and
reservoir, of the high-
performance seawater based polymeric fluid system, with field laboratory
equipment and
specific tests.
Date Recue/Date Received 2022-03-22
19
For the preparation it is necessary to have the following equipment with
minimum requirements, which
are those of the drilling rigs already installed:
1. A weir or mixing tank with a capacity of 45 to 120 m3 (Figure 9, 10 and 11,
letter T), where the
chemical products that make up this fluid will be mixed.
2. Deep well suction and discharge pump with an 8 in suction impeller, which
discharges seawater
to the mixing weir (Figure 9, 10 and 11, letter A).
3. Suction and discharge diaphragm pump, with a pumping capacity of 275 gpm
(Figure 9, 10 and
11, letter B) that will suction and discharge the products to the mixing weir.
4. 275 gpm centrifugal mixing pump connected to a 4 to 8 kg/cm' air
compressor (Figure 9, 10 and
11, letter D).
5. Variable speed metal slurry pump (Figure 9, 10 and 11, letter C) connecting
to the stand pipe
(Figure 9, 10 and 11, letter E).
6. Connecting hoses are made of ethylene propylene diene and/or cross-linked
polyethylene
resistant to chemicals and hydrocarbon derivatives, and operating and handling
pressures of 250
psi. The quantity to be used depends on the on-site operation.
7. Heavy duty 3" diameter stainless steel quick connect fittings.
It will be estimated that a first mode of the process for a reservoir typified
for Middle Cretaceous (MC),
Upper Cretaceous Paleocene Tertiary Breccia (UCPTB) and Upper Cretaceous
Breccia (UCB) with
operational temperature conditions of 80 to 120 C for a high-performance
seawater based polymeric
fluid, at least and not limiting the equipment conditions, comprises the
following stages (Figure 9):
a)
Providing a mixing weir (1) with agitation system with 4 rotating blades with
electric motor.
Date Recue/Date Received 2022-03-22
20
b) Providing a deep well pump (A) and tank mixing pump (D).
c) Providing a 275 gpm pumping capacity suction and discharge diaphragm
pump (B) with
hoses, reinforced for pressure handling with heavy duty stainless steel end
connections.
d) Providing a vessel of 1 m3 capacity (1), containing a suspension
filtrate viscosifier and
reducer, which is a mixture of polyanionic cellulose polymer and extracellular
polysaccharide suspended in mineral oil.
e) Providing a container of 1 m3 capacity (2) , containing a liquid clay
inhibitor, which is a
mixture of potassium chloride, choline chloride and heavy glycol in water.
0 Providing a vessel of 1 m3 capacity (3), containing a liquid
alkalinizer, which is
monoethanolamine in deionized water.
The process of coupling the high-performance seawater-based polymeric fluid
system for reservoir
drilling typified for Middle Cretaceous (MC), Upper Cretaceous Paleocene
Tertiary Breccia (UCPTB)
and Upper Cretaceous Breccia (UCB) with operational temperature conditions of
80 to 120 C comprises
the steps of:
g) Adding the continuous phase, which is seawater, by means of the deep
well pump to the tank
weir, in a concentration of 875 to 956 L/m3, with the weir agitation system
running.
h) Placing the suction and discharge hose and the heavy duty stainless
steel connection, in the
vessel containing a viscosifier and filtrate reducer in suspension, which is
the mixture of
polyanionic cellulose polymer and extracellular polysaccharide suspended in
mineral oil, at
a concentration rate of 9 to 15 L/m3, adding with the diaphragm pump to the
mixing weir
while the agitation is continuous in the mixing tank.
i) Placing the suction and discharge hose and the heavy duty stainless
steel connection in the
container containing a liquid clay inhibitor, which is the mixture of
potassium chloride,
Date Recue/Date Received 2022-03-22
21
choline chloride and heavy glycol in water, at a concentration of 30 to 100
L/m3, adding with
the diaphragm pump to the mixing weir while the agitation is continuous in the
mixing tank.
I) Placing the suction and discharge hose and the heavy duty
stainless steel connection in the
container containing a liquid alkalinizer, which is monoethanolamine in
deionized water, at
a concentration rate of 5 to 10 L/m3, adding with the diaphragm pump to the
mixing weir
while the agitation is continuous in the mixing tank.
k) Completing the continuous stirring time of the seawater-based
polymeric fluid after all
products have been added for a period of 28 to 30 minutes.
It would be desirable that the second modality of the process for a reservoir
typified for Upper Paleocene
Calcareous Body (UPCB) with operational temperature conditions of 80 to 100 C
for a high-
performance seawater-based polymeric fluid, at least and not limiting in
equipment conditions,
comprises the following steps (Figure 10):
a) Providing a mixing weir (1) with agitation system with 4 rotating blades
with electric motor.
b) Providing a deep well pump (A) and tank mixing pump (D).
c) Providing a 275 gpm pumping capacity suction and discharge diaphragm
pump (B) with
hoses, reinforced for pressure handling with heavy duty stainless steel end
connections.
d) Providing a vessel of 1 m3 capacity (1), containing a suspension
filtrate viscosifier and
reducer, which is a mixture of polyanionic cellulose polymer and extracellular
polysaccharide suspended in mineral oil.
e) Providing a container of 1 m3 capacity (2) , containing a liquid clay
inhibitor, which is a
mixture of potassium chloride, choline chloride and heavy glycol in water.
0 Providing a vessel of 1 m3 capacity (3), containing a liquid
alkalinizer, which is
monoethanolamine in deionized water.
Date Recue/Date Received 2022-03-22
22
g) Providing a vessel of 1 m3 capacity (4), containing a stabilizer and
encapsulator of clays in
suspension, which is a mixture of polyacrylamide and calcium carbonate
suspended in
mineral oil.
h) Providing a vessel of 1 m3 capacity (5), containing a liquid
reinforcement inhibitor to inhibit
clays, which is a mixture of potassium chloride, magnesium chloride and glycol
in water.
The process of coupling the high-performance seawater-based polymeric fluid
system for drilling the
Upper Paleocene Calcareous Body (UPCB) typified reservoir comprises the steps
of:
i) Adding the continuous phase, which is seawater, by means of the deep
well pump to the tank
weir, in a concentration of 765 to 902 L/m3, with the weir agitation system
running.
.i) Placing the suction and discharge hose and the heavy duty
stainless steel connection, in the
vessel containing a viscosifier and filtrate reducer in suspension, which is
the mixture of
polyanionic cellulose polymer and extracellular polysaccharide suspended in
mineral oil, at
a concentration rate of 9 to 15 L/m3, adding with the diaphragm pump to the
mixing weir
while the agitation is continuous in the mixing tank.
k) Placing the suction and discharge hose and the heavy duty
stainless steel connection in the
container containing a liquid clay inhibitor, which is the mixture of
potassium chloride,
choline chloride and heavy glycol in water, at a concentration of 30 to 100
L/m3, adding with
the diaphragm pump to the mixing weir while the agitation is continuous in the
mixing tank.
1) Placing the suction and discharge hose and the heavy duty
stainless steel connection in the
container containing a liquid alkalinizer, which is monoethanolamine in
deionized water, at
a concentration rate of 5 to 10 L/m3, adding with the diaphragm pump to the
mixing weir
while the agitation is continuous in the mixing tank.
m) Placing the suction and discharge hose, and the heavy duty stainless
steel connection, in the
Date Recue/Date Received 2022-03-22
23
container containing a stabilizer and encapsulator of clays in suspension,
which is a mixture
of polyacrylamide and calcium carbonate suspended in mineral oil, at a
concentration rate
of 4 to 10 L/m3, adding with the diaphragm pump to the mixing weir while the
agitation is
continuous in the mixing tank.
n) Placing
the suction and discharge hose, and the heavy duty stainless steel connection
in the
container containing a liquid reinforcement inhibitor to inhibit clays, which
is a mixture of
potassium chloride, magnesium chloride and glycol in water, at a concentration
rate of 50 to
100 L/m3, adding with the diaphragm pump to the mixing weir, while the
agitation is
continuous in the mixing tank.
o)
Completing the continuous stirring time of the seawater-based polymeric fluid
after all
products have been added for a period of 28 to 30 minutes.
It is important that the third mode of the process for a reservoir typified
for Upper Jurassic Titonian
(JUT) and Upper Jurassic Kimmeridian (UJK) with high operational temperature
conditions of 120 to
170 C, for a high-performance seawater based polymeric fluid, at least and
not limiting in equipment
conditions, comprises the following steps (Figure 11):
a) Providing a mixing weir (T) with agitation system with 4 rotating blades
with electric motor.
b) Providing a deep well pump (A) and tank mixing pump (D).
c)
Providing a 275 gpm pumping capacity suction and discharge diaphragm pump (B)
with
hoses, reinforced for pressure handling with heavy duty stainless steel end
connections.
d) Providing a vessel of 1 m3 capacity (1), containing a viscosifier
and rheological stabilizer in
suspension for high temperature, which is a mixture of extracellular
polysaccharide,
cellulose polyanionic polymer and potassium chloride suspended in mineral oil.
e)
Providing a vessel of 1 m3 capacity (2), containing a thermal stabilizer in
suspension, which
Date Recue/Date Received 2022-03-22
24
is a suspension of sulfated acrylic polymeric in mineral oil.
0 Providing a vessel of 1 m3 capacity (3), containing a high
temperature filter reducer in
suspension, which is a suspension of acrylate copolymer in mineral oil.
g) Providing a container of 1 m3 capacity (4), containing a liquid clay
inhibitor, which is a
mixture of potassium chloride, choline chloride and heavy glycol in water.
h) Providing a vessel of 1 m3 capacity (5), containing a liquid
alkalinizer, which is
monoethanolamine in deionized water.
The process of coupling the high-performance seawater-based polymeric fluid
system for reservoir
drilling typified for Jurassic Upper Titonian (JUT) and Upper Jurassic
Kimmeridian (UJK) with high
operational temperature conditions of 120 to 170 C comprises the steps of:
i) Adding the continuous phase, which is seawater, by means of the deep
well pump to the tank
weir, in a concentration of 859 to 945 L/m3, with the weir agitation system
running.
I) Placing the suction and discharge hose and the heavy duty
stainless steel connection in the
container containing a viscosifier and theological stabilizer in suspension
for high
temperature, which is the mixture of extracellular polysaccharide, cellulose
polymer
polyanionic polymer and potassium chloride suspended in mineral oil, at a
concentration
rate of 9 to 14 L/m3, adding with the diaphragm pump to the mixing weir while
the agitation
is continuous in the mixing tank.
k) Placing the suction and discharge hose, and the heavy duty stainless
steel connection, in the
container containing a thermal stabilizer in suspension, which is a suspension
of sulfated
acrylic polymer in mineral oil, at a concentration rate of 5 to 8 L/m3, adding
with the
diaphragm pump to the mixing weir, while the agitation is continuous in the
mixing tank.
1) Placing the suction and discharge hose and the heavy duty
stainless steel connection in the
vessel containing a high temperature filter reducer in suspension, which is a
suspension of
Date Recue/Date Received 2022-03-22
25
acrylate copolymer in mineral oil, at a concentration rate of 6 to 9 L/m3,
adding with the
diaphragm pump to the mixing weir while the agitation is continuous in the
mixing tank.
m) Placing the suction and discharge hose and the heavy duty stainless
steel connection in the
container containing a liquid clay inhibitor, which is a mixture of potassium
chloride, choline
chloride and heavy glycol in water, at a concentration of 30 to 100 L/m3,
adding with the
diaphragm pump to the mixing weir while the agitation is continuous in the
mixing tank.
n) Placing the suction and discharge hose and the heavy duty stainless
steel connection in the
container containing a liquid alkalinizer, which is a monoethanolamine in
deionized water,
at a concentration rate of 5 to 10 L/m3, adding with the diaphragm pump to the
mixing weir
while the agitation is continuous in the mixing tank.
o) Completing the continuous stirring time of the seawater-based polymeric
fluid after all
products have been added for a period of 28 to 30 minutes.
Verification, inspection and validation to meet the quality and technical
parameters of the high-
performance seawater-based polymeric fluid system in formation and reservoir
drilling, with field
laboratory equipment and specific tests, which are established in the rock-
fluid interaction.
An application carried out of the high-performance seawater based polymeric
fluid to verify that the
formulation presented is suitable and meets the physicochemical properties
such as: rheology,
thixotropy, lubricity, thermal stability, chemical inhibition, solubility in
15% HC1 and compatibility with
formation fluids for the drilling of the reservoir stage in loss of
circulation zone of wells in Ku, Maloop,
Zaap and Ayatsil fields, belonging to the top of the Upper Paleocene (PS),
formation with mineralogical
concentrations of highly reactive clays. The reference standards are API RP 13
B-1, 4th. 2009 Issue,
Errata 1 August 2014; reaffirmed in March 2016. Mexican Standard NMX-L-167-
SCFI-2004; and
PEMEX Technical Specification P.7.0841.01:2015.
Date Recue/Date Received 2022-03-22
26
The following table shows, referring to Figure 4, the stages, bit, proposed
density and depth of settlement
(depth measurement, mD).
Proposed
Stage Auger
density Settees demo (null
TR 30 36' 103 200
TR 20' 26` I 10 600
TR 16' 18W 145 1600
TR 133l$" 14 19 175 2100
TR 1 7)8" 12 1)4" 1.75 3055
LINER
1O5' 103 4085
95)8
LINER
1.65 4820
7 5/8'
AD 6 1.25 5240
The following table shows, referring to Figure 8, the lithology per interval
ranges.
Interval Lithology
90 % light gray lutite, soft to semi-hard, slightly calcareous.
4030-4035 m 10% light gray and greenish gray
bentonite.
Traces of reddish brown limolite.
80% lihtray lutite, soft to semi-hard, slightly calcareous.
10% reddish brown limolite.
4035-4045 in
% light gray and greenish gray bentonite.
Traces of light gray, semi-compact Wackestone-Packestone with intergranular
porosity.
80% light gray lutite, soft to semi-hard, slightly calcareous.
10% reddish brown limolite.
4045-4055 in 10 % light gray and greenish gray
bentonite.
Traces of light gray, semi-compact Wackestone-Packestone with intergranular
porosity.
NOTE: Sample heavily ground and contaminated with chemical material.
50% light gray lutire, soft to semi-hard, slightly calcareous.
20% reddish brown limolite.
4055-4060
20% light gray and greenish gray bentonite.
m
10 % Mudstone light may and light brown semi-compacted in Darts slightly
dolomitized.
Traces of white and light brown microcrystalline dolomite with
intercrystalline porosity.
NOTE: Sample made up of fine cuttings.
30 %white and light brown microcrystalline dolomite with intercrystalline
porosity.
30% reddish brown limolite.
4060-4065
%light gray lutite, soft to semi-hard, slightly calcareous.
m
20% light gray and light brown semi-compacted mudstone in slightly dolomitized
parts.
Traces of light gray and greenish gray bentonite.
NOTE: Sample heavily ground.
100 % Breccia consisting of angular fragments of Mudstone-Wackestone and
white, light brown and light gray
40654115 m
Dolomite, with microcrystalline porosity.
¨
Traces of reddish brown limolite.
Sporadic fragments of light gray bentonite.
The following table shows the physicochemical properties data obtained onboard
for the high-
Date Recue/Date Received 2022-03-22
27
performance seawater-based polymeric fluid on a daily basis during the
drilling of the Ayatsil 261 well,
and verifies the rheological-thixotropic behavior. Note that the results
obtained for the rheological and
thixotropic values are the ideal and programmed values for an adequate
cleaning and suspension of
cuttings during pump stoppages at the connections and during total loss of
circulation.
I __________________________________________________________________________ d
Date ;7.. f,.,,91:2;.121 i 25,.01.2n1 1
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11:00 PI l 11 1115 PIO 11:00PM 11:00 PM
: 4070 4095 4161 4170 4222 4a1 4231
4274 4281
glcm2 1.03 1.03 1.03 1O3 1 o3 -Lii3 1.03
1.03 1.03 ,
94, 64 67 6.6 67 641. 59 59 58 58
vi,.iii:.sity 1
Aridlirciis pc 49 4t IS. 0 0 4g 49 49
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L600 Deflex 1 56 56 53 S5 : 50 5C. 50
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L I.181/ 44 44 42 43 .181 j14. 58 58 38
L200 Deflax I 38 at - '33 '39 a 1 31 31
510 30
L100 Dellex 29 31 30 31, 2 ( 2 ,' 2 ii 25
25
L6 Deflex 1 l 1 12
, __________________________________________________________________________
L3 . Doflex 0 10 1i :0 9
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Plastic
cP 12 12 11 12 11 11 11 11 11
liscosity
IN106
C,Hcie It Paint 32 32 31 31 28 28 28 27 27
ft2
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Gel 10 ne 18.1100n. 4.4 15 14 13 13 18. 13 12
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Watfir % 99 g9 .99 99 99 99 99 99 99
pH : : : : : 10 . 10 10 0 10.0 i00 10.0
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2.5 2.5
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5000 '2 5000 2 5000 23000 2.517120
_________________________________________________ - __________
MET Kg/m' O:' LI Ci 0 0 0 0 0
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4_44_,:ANI PPm 2400 2.4. 2400 2400 . 2400 200
2400. 2400 2400
Test 1: Determination of rheological and thixotropic properties of the fluid.
The theological properties should be obtained for the seawater-based polymeric
fluid when thermally
stabilized at 65 C, when contaminated with CO2, and after the thermal effect
tests at 120 to 135 C,
according to the corresponding field (Figure 12 and following table). The
results show that it maintains
Date Recue/Date Received 2022-03-22
28
its rheological and thixotropic properties at 120 'C.
The following table, referring to Figure 12, shows the results of the
determination of rheological and
thixotropic properties of the high-performance seawater-based polymeric fluid
stabilized at 65 C,
contaminated with CO2, and with temperature conditions of 120 C.
Farm Viscometer
7; $ $ Obef100112) ' 57 63 53 38
4 i lb/1O0821 43 40 40 30
op ( bwritif") 37 34 34 I 25
105 (Ibtiooft2) 28 25 26 21 .
5_ (10/100W) ' 10 10 9 10
1 L3 ILIVICX)ft ) _, 8 8 8 8
,
1 Va (cP) 28.5 26.6 26.5 19
, 0 (c,,e) 14 13 13 8
Pe (19/100ft2 ,) 20 27 27 22
poi 109 (Ib1100ft2) 9 9 I 9 9 _
I Gel 10mira Pb1100ft2) 11 11 10 11
12 u 12 12 12
Test 2: Determination of density and Marsh viscosity.
The density and viscosity properties should be obtained for the seawater-based
polymeric fluid, when
thermally stabilized at 65 C, when contaminated with CO2, and after the
thermal effect tests at 120 to
135 C, according to the corresponding field (following tables). The results
show that it maintains its
density and viscosity properties at 120 C.
The following tables show the results of the density and Marsh viscosity
determination of the high-
performance seawater based polymeric fluid stabilized at 65 C, contaminated
with CO2, and with
temperature conditions of 120 C.
Sludge balance
Flusi . K It* .= ¨ =ao
1.12 1.12 112 112
___________________________________________________________________ _¨
Table of Densities for M-1 Fluids (Ku-Maloob:Zaap Fields) ¨
Date Recue/Date Received 2022-03-22
29
IPRolItng Thermal Stabil.ty CO, contamination Thennm effect
68 s @ 22 1 'C 64 s a 34.4 'C N,A 7[45 8
Si
Marsh Viscosity Table for M 1 Fluids (Ku Maloob Zaap Fields)
Test 3: API filtering.
The API filtering property should be obtained for the seawater-based polymeric
fluid, when thermally
stabilized at 65 C, when contaminated with CO2, and after the thermal effect
tests at 120 to 135 C,
according to the corresponding field (following table). The results show that
it maintains its API filtering
property at 120 C.
The following table shows the results of the API filtration of the high-
performance seawater based
polymeric fluid stabilized at 65 C, contaminated with CO2, and with
temperature conditions of 120 C.
. _
¨ ' , Before Rolling II Thermal Stability CO
contamination Thermal effect
(65' C) l (65'C) 0
2O'CL =
,,,,, ma,,m04iiltf aton (m1/30 illn1i . .
?OP .''W,,,7711,,,14, ,,g,2 pr,.orpp. e;p1q:Jimpu iii
, HlIld M I I Ku
Za Frelc 4.2 , 3/ 4 3 5,6
4,6 not) dp k } ________________________ I I
Table with test results of API filtrate testing of M-1 fluids
Test 4: APAT filtering at 120 C at 500 psi differential pressure.
The APAT filtering property should be obtained for the seawater based
polymeric fluid, when thermally
stabilized at 65 C, when contaminated with CO2, and after the thermal effect
tests at 120 C, 500 psi
differential pressure, according to the corresponding field (following table).
The results show that it
maintains its APAT filtering property at 120 C.
The following table shows the results of the APAT filtration of the high-
performance seawater based
polymeric fluid stabilized at 65 C, contaminated with CO2, and with
temperature conditions of 120 C
Date Recue/Date Received 2022-03-22
30
and 500 psi.
Preis I Ittatn Itin1/30intri) õ
I, Fluid M.11
(Ku- Malo0b-Zaap I 8.8 x 2=17.6 14.2 x 2=28.4 12 x 2= 24
14.8 x 2= 29.6
Table with results of the APAT filtrate test of M-1 fluids
Test 5: Solids content (Retort).
The solids content (retort), should be obtained for the seawater-based
polymeric fluid, when thermally
stabilized at 65 C, when contaminated with CO2, and after the thermal effect
tests at 120 C, according
to the corresponding field (following table). The results show that it
maintains its solids content (Retort)
at 120 C.
The following table shows the results of the solids content (Retort) of the
high-performance seawater
based polymeric fluid stabilized at 65 C, contaminated with CO2, and with
temperature conditions of
120 'C.
Retort
,
Fluid Mo1 (Ku- Oil (o) 2 2 2 2
Malbob-Zaap Solid (s) 6 B 8
Fields) Water (W) 92 90 90
90
Table of results Retort for M-1 fluid (Ku-Maloob-Zaao fields)
Test 6: Rock-fluid interaction.
The rock-fluid interaction property, i.e. cation exchange capacity, meq/100 g,
can be observed in the
results in Figure 13. Linear swelling (Figure 14 and the following table), the
height of the pellet is
observed to be 20. 3 % in 20 h, the behavior of the percentage of linear
swelling versus a blank (seawater)
Date Recue/Date Received 2022-03-22
31
can be observed in Figure 15, which remains constant.
The following table shows the result of the determination of the linear
swelling (Figure 14) where the
height of the tablet is 20. 3% in 20 hours.
Fields)
Linear Height iriches) '
sy.pAirg
0.578 20.3
Test 7: Dispersion tests.
The weight of the cuttings in a compacted pellet at the exit of the reservoir
drilling process versus the
drying of the same pellet at 105 C for three hours in oven drying is observed
(following tables).
The following tables show the results of the dispersion test of the pellet
output and drying of the pellet.
Compact* III, Initial Weight Tablet
Weight Trimming(g)
1111(g)
M-1 tablet 20.0086 19.9221
Dispersion
Weight of watch Weight watch Final weights
dispersion
9Iass glass + Tablet . MF tablet
34.5893 54.2512 1 19.6619
1.30
___________________________________________________________________________ 1
Test 8: Accretion tests.
The results of the accretion test, with an accretion of 0.33 % for the
seawater-based polymeric fluid,
rolling a cell at 85 C for 4 h, with oven drying after cooling to ambient
temperature for 2 h, at 65 C.
The following tables show the accretion test results, with an accretion of
0.33 % for the seawater-based
polymeric fluid.
Date Recue/Date Received 2022-03-22
An - 1010 moso Th, Amu
1111111111111' ____________________ Initial weight (gr) Final weight (9)
Initial
325.91 0 326.99 20 0098
Table of pipe weight before and after test for fluid M-1
tcretion
11 1M-1 flukt 0.33
Table of % Accretion for M-1 fluid (Ku-Maloob-Zaap F e
Test 9: Capillary suction test.
.. The capillary suction time, using the API filtrate thermally stabilized at
65 C subsequently mixed and
wetted with a mixture of 2 g of shales (clays). The time obtained is 33.3 s.
Test 10: Lubricity.
The torque reached with the load of 172.5 Kg/cm at intervals of 0, 1, 2, 3 and
4 minutes, the average,
and a correction factor for the high-performance seawater based polymeric
fluid. The reading for
seawater should be between 34 4, so the correction factor is 1.01 (following
tables).
The following tables show torque results with a load of 172.5 Kg/cm, at
intervals of 0, 1, 2, 3, and 4
minutes, the average, and a correction factor for the high-performance
seawater based polymeric fluid.
The reading for seawater should be between 34 4, so the correction factor is
1.01.
Lubricity Coefficient
0.18
Lubricimeter torque (lb/in) ,
'Correction
0 1 min 2 min 3 mitt f 4 min
'9 1 factor
33 34 35 36 33.4
19 18 18 17 18.4 1.01
____________________________________________________________________ a
Lut;Ucity table for M-1 fluids
Date Recue/Date Received 2022-03-22
33
Test 11: Solubility in 15% HC1.
The solubility in HC1 at 15 % is determined due to the fact that the system is
cleaned with HC1. If the
fluid is not solubilized, it can cause clogging and sieves. As seen in the
following table, this is fulfilled.
The following tables show the solubility in 15% HC1, an acid used in the
cleaning of the drilling system.
It is a seawater-based polymeric fluid soluble in 15% HCI, compatible with the
cleaning of the system.
Solubility in 15% HCI.
M-1 fluid
__________________________________________________ YES NO
I 1, Yes, Complies (traces) 1
Table of Solubility in HG! at 15%.
The above tests determine that the fluid of the present invention is
satisfactory in quality, and is validated
for use.
According to the above, specific modalities have been described for the
purpose of elucidating the scope
of application in the drilling of many reservoirs with different mineral
formations with total, partial or
intermittent loss of circulation, with highly reactive clays.
The above-described invention is not limited except for the appended claims.
Date Recue/Date Received 2022-03-22
