CA3130499C - 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 - Google Patents

Abstract

ABS TRAC T High-performance polymeric seawater-based fluids for drilling total loss of circulation reservoirs with highly reactive clays for Middle Cretaceous, Upper Cretaceous Paleocene Tertiary Breccia and Upper Cretaceous Breccia are disclosed. Processes for making these fluids are also disclosed. The fluid includes an aqueous base, a suspension filtrate viscosifier and reducer, a liquid clay inhibitor and a liquid alkalinizer. The aqueous base consists of seawater having a concentration of 875 to 956 L/m3. The suspension filtrate viscosifier and reducer consists of a mixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil, the mixture having a concentration of 9 to 15 L/m3. The liquid clay inhibitor consists of a mixture of potassium chloride, choline chloride, and heavy glycol in water, the mixture having a concentration of 30 to 100 L/m3. The liquid alkalinizer consists of a monoethanolamine in deionized water having a concentration of 5 to 10 L/m3. Date Recue/Date Received 2022-03-22

Description

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

2 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 Date Recue/Date Received 2022-03-22

3 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.
Date Recue/Date Received 2022-03-22

4 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 Date Recue/Date Received 2022-03-22

5 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.
Date Recue/Date Received 2022-03-22

6 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

7 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

8 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).
Date Recue/Date Received 2022-03-22

9 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 (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 Date Recue/Date Received 2022-03-22

11 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 Date Recue/Date Received 2022-03-22

12 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 Date Recue/Date Received 2022-03-22

13 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'.
Date Recue/Date Received 2022-03-22

14 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.
Date Recue/Date Received 2022-03-22

15 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:
Date Recue/Date Received 2022-03-22

16 Product Function Concentration [L/m3].
Seawater Continuous phase 765 to 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 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 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 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 Date Recue/Date Received 2022-03-22

17 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.

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.

%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 :=6;1,';.T.1:2 ' ;:7T:':2r..=,: = 2 .;1-; ' :2021 29/0 ';.7.0:.1 3010112021 7. ' ili '1ii.n:' 0 ' :02;7021 Pararnethrs Report 7 1 0 9 10 II 12 13 14 .

Oiii e: D 42 47 MA fiiI/ANI,A . N. NIA NIA
'Erni, yature 2:00 PM 11:00 PM 11:00 PM 11:03PM 11,00 PM
11:00 PI l 11 1115 PIO 11:00PM 11:00 PM
: 4070 4095 4161 4170 4222 4a1 4231 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 lemperature. .4e.4-. - -4-L600 Deflex 1 56 56 53 S5 : 50 5C. 50 ... - -Deflex L I.181/ 44 44 42 43 .181 j14. 58 58 38 L200 Deflax I 38 at - '33 '39 a 1 31 31 L100 Dellex 29 31 30 31, 2 ( 2 ,' 2 ii 25 L6 Deflex 1 l 1 12 , __________________________________________________________________________ L3 . Doflex 0 10 1i :0 9 0 .
Plastic cP 12 12 11 12 11 11 11 11 11 liscosity C,Hcie It Paint 32 32 31 31 28 28 28 27 27 ft2 16,1i 00 G&10. 11 12 11 11 10 10 10 10 14, ft' Gel 10 ne 18.1100n. 4.4 15 14 13 13 18. 13 12 fe ,42I f.88.r 8,4 MI. $ 10 16 9 .ic:( la Fr, 10 10 1' 1 . 1' 1 '1 1 1 1 1 % t 1 . 1 1 . 1 1 1 .1' 1 LI I % 0 0 0 0 '0 0 0 JO 0 Watfir % 99 g9 .99 99 99 99 99 99 99 pH : : : : : 10 . 10 10 0 10.0 i00 10.0 10.0 10.0 Ma .
4t,;N(,11 MI 2.5 2.5 .; ''', 2 b 2.5 '2 b 2.5 2.5 :1:1=1:,(1.10$ mil 75ono .::50171 '5[-.)071 51)01:1 2 5000 '2 5000 2 5000 23000 2.517120 _________________________________________________ - __________ MET Kg/m' O:' LI Ci 0 0 0 0 0 IJ _ -- -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 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 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

Claims (21)

34

1. A high-performance polymeric seawater-based fluid for drilling total loss of circulation reservoirs with highly reactive clays for Middle Cretaceous (MC), Upper Cretaceous Paleocene Tertiary Breccia (UCPTB) and Upper Cretaceous Breccia (UCB) with operational temperature conditions of 80 to 120 C comprising:
an aqueous base consisting of seawater, a suspension filtrate viscosifier and reducer consisting of a mixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil, a liquid clay inhibitor consisting of a mixture of potassium chloride, choline chloride, and heavy glycol in water, and a liquid alkalinizer consisting of a monoethanolamine in deionized water, said fluid being characterized in that the seawater has a concentration of 875 to 956 L/m3; the mixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil as the suspension filtrate viscosifier and reducer has a concentration of 9 to 15 L/m3; the mixture of potassium chloride, choline chloride, and heavy glycol in water as the liquid clay inhibitor has a concentration of 30 to 100 L/m3; and the monoethanolamine in deionized water as the liquid alkalinizer has a concentration of 5 to 10 L/m3.

2. The high-performance polymeric seawater-based fluid of claim 1, wherein the reservoir comprises formations for Middle Cretaceous (MC), Upper Cretaceous Paleocene Tertiary Breccia (UCPTB) and Upper Cretaceous Breccia (UCB) with highly reactive clays.

3. A process for forming a high-performance seawater based polymeric fluid for total loss of circulation reservoir drilling as claimed in claim 1 for Middle Cretaceous (MC), Upper Cretaceous Date Recue/Date Received 2022-03-22 Paleocene Tertiary Breccia (UCPTB) and Upper Cretaceous Breccia (UCB) with operational temperature conditions of 80 to 120 C, the process comprising:
a) providing a weir or mixing tank with the agitation system;
b) providing a deep well suction and discharge pump;
c) providing a centrifugal mixing pump;
d) providing a diaphragm pump with suction and discharge connections and hoses;
e) providing a variable speed metallic mixing pump;
f) providing a vessel containing the suspension filtrate viscosifier and reducer which is themixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil;
g) providing a container containing the liquid clay inhibitor, which is the mixture of potassium chloride, choline chloride and heavy glycol in water;
h) providing a container containing the liquid alkalinizer, which is monoethanolamine in deionized water;
i) adding the continuous phase, which is seawater, with the deep well pump to the weir or mixing tank with the agitation system running;
j) placing the suction and discharge hose and the connection in the vessel containing the suspension filtrate viscosifier and reducer, 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, pumping 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 connection in the vessel containing the 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 pumping 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 connection in the vessel containing the Date Recue/Date Received 2022-03-22 liquid alkalinizer, which is the monoethanolamine in deionized water, at a concentration of to 10 L/m3, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank; and m) 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.

4. The process of claim 3, wherein in step b) the deep well suction and discharge pump has an 8 in suction impeller.

5. The process of claim 3, wherein in step d) the suction and discharge diaphragm pump has a pumping capacity of 275 gpm.

6. The process of claim 3, wherein in step c) the mixing centrifuge pump has a pumping capacity of 275 gpm.

7. The process of claim 3, wherein in step d) the connections are of stainless steel of 3 in diameter and the hoses are of ethylene propylene diene and/or cross-linked polyethylene resistant to chemical products.

8. A high-performance seawater-based polymeric fluid for total loss of circulation reservoir drilling with highly reactive clays typed for Upper Paleocene Calcareous Body (UPCB) with operational temperature conditions of 80 to 100 C comprising:
an aqueous base consisting of seawater, a suspension filtrate viscosifier and reducer consisting of a mixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil, Date Recue/Date Received 2022-03-22 a liquid clay inhibitor consisting of a mixture of potassium chloride, choline chloride and heavy glycol in water, a liquid alkalinizer consisting of a monoethanolamine in deionized water, a stabilizer and encapsulator for clays in suspension consisting of a mixture of polyacrylamide and calcium carbonate suspended in mineral oil, and a reinforcing inhibitor for inhibiting liquid clays consisting of a mixture of potassium chloride, magnesium chloride and glycol in water, said fluid characterized in that seawater has a concentration of 765 to 902 L/m3; the mixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil as the suspension filtrate viscosifier and reducer has a concentration of 9 to 15 L/m3; the mixture of potassium chloride, choline chloride and heavy glycol in water as the liquid clay inhibitor has a concentration of 30 to 100 L/m3; the monoethanolamine in deionized water as the liquid alkalinizer has a concentration of 5 to 10 L/m3, the mixture of polyacrylamide and calcium carbonate suspended in mineral oil as stabilizer and encapsulator of clays in suspension has a concentration of 4 to 10 L/m3, and the mixture of potassium chloride, magnesium chloride and glycol in water as the reinforcing inhibitor to inhibit liquid clays has a concentration of 50 to 100 L/m3.

9. The high-performance seawater-based polymeric fluid of claim 8, wherein the reservoir comprises formations for Upper Paleocene Calcareous Body (UPCB) with highly reactive clays.

10. A process for forming a high-performance seawater based polymeric fluid for total loss of circulation reservoir drilling as claimed in claim 8 for Upper Paleocene Calcareous Body (UPCB) with operating temperature conditions of 80 to 100 C comprising:
a) providing a weir or mixing tank with the agitation system;
b) providing a deep well suction and discharge pump;
Date Recue/Date Received 2022-03-22 c) providing a centrifugal mixing pump;
d) providing a diaphragm pump with suction and discharge connections and hoses;
e) providing a variable speed metallic mixing pump;
f) providing a vessel containing the suspension filtrate viscosifier and reducer which is the mixture of polyanionic cellulose polymer and extracellular polysaccharide suspended in mineral oil;
g) providing a container containing the liquid clay inhibitor, which is the mixture of potassium chloride, choline chloride and heavy glycol in water:
h) providing a container containing the liquid alkalinizer, which is the monoethanolamine in deionized water;
i) providing a vessel containing the suspended clay stabilizer and encapsulator, which is the mixture of polyaciylamide and calcium carbonate suspended in mineral oil;
j) providing a container containing the reinforcing inhibitor for inhibiting liquid clays, which is the mixture of potassium chloride, magnesium chloride and glycol in water;
k) adding the continuous phase, which is seawater, with the deep well pump to the weir or mixing tank with the agitation system running;
1) placing the suction and discharge hose and the connection in the vessel containing the suspension filtrate viscosifier and reducer, 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, pumping 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 connection in the vessel containing the 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, pumping 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 connection in the vessel containing the Date Recue/Date Received 2022-03-22 liquid alkalinizer, which is monoethanolamine in deionized water, at a concentration of 5 to 10 L/m3, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank;
o) placing the suction and discharge hose and the connection in the vessel containing the stabilizer and encapsulator of clays in suspension, which is the mixture of polyacrylamide and calcium carbonate suspended in mineral oil, at a concentration rate of 4 to 10 L/m3, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank;
p) placing the suction and discharge hose and the connection in the vessel containing the reinforcing inhibitor to inhibit clays liquid, which is the mixture of potassium chloride, magnesium chloride and glycol in water, at a concentration of 50 to 100 L/m3, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank; and q) 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.

11. The process of claim 10, wherein in step b) the deep well suction and discharge pump has an 8 in suction impeller.

12. The process of claim 10, wherein in step d) the suction and discharge diaphragm pump has a pumping capacity of 275 gpm.

13. The process of claim 10, wherein in step c) the centrifugal mixing pump has a pumping capacity of 275 gpm.
Date Recue/Date Received 2022-03-22

14. The process of claim 10, wherein in step d) the connections are 3 in diameter stainless steel and the hoses are chemical resistant ethylene propylene diene and/or cross-linked polyethylene.

15. A high-performance seawater-based polymeric fluid for total loss of circulation reservoir drilling with highly reactive clays for Jurassic Upper Titonian (JUT) and Upper Jurassic Kimmeridian (UJK) with high operational temperature conditions of 120 to 170 C comprising:
an aqueous base consisting of seawater, a high temperature suspension viscosifier and rheology stabilizer in suspension consisting of a mixture of extracellular polysaccharide, cellulose-polyanionic polymer and potassium chloride suspended in mineral oil, a thermal stabilizer in suspension consisting of a suspension of sulfated acrylic polymer in mineral oil, a high temperature suspension filter reducer consisting of a suspension of acrylate copolymer in mineral oil, a liquid clay inhibitor consisting of a mixture of potassium chloride, choline chloride and heavy glycol in water, and a liquid alkalinizer consisting of a monoethanolamine in deionized water, said fluid being characterized in that the seawater has a concentration of 859 to 945 L/m3; the mixture of extracellular polysaccharide, cellulose-polyanionic polymer and potassium chloride suspended in mineral oil as the viscosifying agent and rheological stabilizer in suspension for high temperature has a concentration of 9 to 14 L/m3; the suspension of sulfated acrylic polymer in mineral oil as the thermal stabilizer in suspension has a concentration of 5 to 8 L/m3; the suspension of acrylate copolymer in mineral oil as the high temperature suspension filtrate reducer in suspension has a concentration of 6 to 9 L/m3, the mixture of potassium chloride, choline chloride and heavy glycol in water as the liquid clay inhibitor has a concentration of 30 to 100 L/m3, and Date Recue/Date Received 2022-03-22 the monoethanolamine in deionized water as the liquid alkalinizer has a concentration of 5 to 10 L/m3.

16. The high-performance seawater-based polymeric fluid of claim 15, wherein the reservoir comprises formations for Upper Jurassic Titonian (JUT) and Upper Jurassic Kimmeridian (UJK) with highly reactive clays.

17. A process for forming a high-performance seawater based polymeric fluid for total loss of circulation reservoir drilling as claimed in claim 15 for Jurassic Upper Jurassic Titonian (JUT) and Upper Jurassic Kimmeridian (UJK) with high operational temperature conditions of 120 to 170 C
comprising:
a) providing a weir or mixing tank with an agitation system;
b) providing a deep well suction and discharge pump;
c) providing a centrifugal mixing pump;
d) providing a diaphragm pump with suction and discharge connections and hoses;
e) providing a variable speed metallic mixing pump;
0 providing a vessel containing a high temperature suspension viscosifier and rheology stabilizer in suspension which is a mixture of extracellular polysaccharide, polyanionic cellulose polymer and potassium chloride suspended in mineral oil;
g) providing a vessel containing a suspended thermal stabilizer, which is a suspension of sulfated acrylic polymer in mineral oil;
h) providing a vessel containing a suspended high temperature suspension filtrate reducer, which is a suspension of acrylate copolymer in mineral oil;
i) providing a container containing a liquid clay inhibitor, which is a mixture of potassium chloride, choline chloride and heavy glycol in water;
j) providing a container containing a liquid alkalinizer, which is a monoethanolamine in Date Recue/Date Received 2022-03-22 deionized water;
k) adding the continuous phase, which is seawater, with the deep well pump to the weir or mixing tank with the agitation system running, at a concentration of 859 to 945 L/m3;
1) placing the suction and discharge hose and the connection in the vessel containing the viscosifier and rheological stabilizer in suspension for high temperature, which is the mixture of extracellular polysaccharide, polyanionic cellulose polymer and potassium chloride suspended in mineral oil, at a concentration of 9 to 14 L/m3, pumping 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 connection in the vessel containing the thermal stabilizer in suspension, which is the suspension of sulfated acrylic polymer in mineral oil, at a concentration of 5 to 8 L/m3, pumping 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 connection in the vessel containing the high temperature suspension filter reducer in suspension, which is the suspension of acrylate copolymer in mineral oil, at a concentration of 6 to 9 L/m3, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank;
o) placing the suction and discharge hose and the connection in the container containing the 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, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank;
p) placing the suction and discharge hose and the connection in the vessel containing the liquid alkalinizer, which is the monoethanolamine in deionized water, at a concentration rate of 5 to 10 L/m3, pumping with the diaphragm pump to the mixing weir, while the agitation is continuous in the mixing tank; and q) 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.
Date Recue/Date Received 2022-03-22

18. The process of claim 17, wherein in step b) the deep well suction and discharge pump has an 8 in suction impeller.

19. The process of claim 17, wherein in step d) the suction and discharge diaphragm pump has a pumping capacity of 275 gpm.

20. The process of claim 17, wherein in step c) the mixing centrifuge pump has a pumping capacity of 275 gpm.

21. The process of claim 17, wherein in step d) the connections are 3 in stainless steel and the hoses are chemical resistant ethylene propylene diene and/or cross-linked polyethylene.
Date Recue/Date Received 2022-03-22