Drilling fluid additive compositions and drilling fluids containing the drilling fluid additive compositions

Abstract

Compositions and methods of using a drilling fluid additive composition is disclosed. The drilling fluid additive composition can contain a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and / or a fluid loss control additive.

Description

DESCRIPTIONDRILLING FLUID ADDITIVE COMPOSITIONS AND DRILLING FLUIDS CONTAINING THE DRILLING FLUID ADDITIVE COMPOSITIONS FIELD OF INVENTION

[0001] This disclosure generally relates to drilling fluid additive compositions, and drilling fluids containing the drilling fluid additive compositions. ’The drilling fluid additive compositions can contain a dry blend of a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and a fluid loss control additive. The drilling fluids containing the drilling fluid additive compositions can have desired yield point, plastic viscosity, electric stability, and / or high temperature high pressure (HTHP) fluid loss properties.BACKGROUND ART

[0002] Drilling fluids, also known as drilling muds, are used during drilling wellbores into subterranean well formations. Drilling fluids are used for maintaining well control, maintaining chemical and mechanical stability of the wellbore, lubricating and maintaining temperature of the drill bits and other drilling tools, and removing drill cuttings from the wellbore. There are primarily three types of drilling fluids, oil based fluids, water based fluids, and synthetic based fluids. Oil based fluids provide several advantages over water based and synthetic based fluids. Oils are inherently more lubricating than water. Additionally, oil based fluids are more tolerant to contaminants, and have a greater stability at high temperatures. Oil based fluids can also support higher drilling rates and thereby provide higher drilling efficiency. However, oil based fluids are less environmental friendly than water based fluids.

[0003] Oil based drilling fluids contain oil as a continuous phase with small amounts of water dispersed within the continuous phase. Oil based fluids contain additives, such as emulsifiers, viscosifiers, wetting agents, that are used to deal with the challenges posed by the conditions and / or environment at which the drilling is performed. The additives are added separately to the oil at the drilling site to prepare the drilling fluid. However, the separate addition of the additives at the drilling site causes handling, storage, and logistic problems. For example, storage space at the drilling sites are generally limited, but storing the additives separately at the drilling sites require large storage space. Also, separate addition of the different additives to the oil increases the mixing time required for preparing the drilling fluids. Increased mixing time can increase man hours required to produce the drilling fluids, which296204148.1 - 1 -can increase the cost of the drilling process. Additionally, liquid emulsifiers are often used with oil based drilling fluids. The liquid emulsifiers have relatively high volume and therefore have high transportation cost, take larger storage space at the drilling sites, and / or have high disposal cost.SUMMARY OF THE INVENTION

[0004] A solution to at least one or more of the aforementioned problems associated with oil based drilling fluids is provided. The solution can include providing dry particulate free flowing drilling fluid additive compositions. The dry particulate (e.g., powder) compositions can include several additives and can be tuned or modified for particular well formations. An advantage of the dry particulate compositions of the present invention is that they can include a multitude of additives and can be added to drilling fluids in one application, which can reduce the mixing time required to prepare the drilling fluid. Drilling fluid additive compositions of the present invention are also readily dispersible in the drilling fluid. Additionally, the dry -state of the additive compositions allows for more cost and / or time¬ efficient storage and / or transportation of the additive compositions when compared with liquid additive compositions. The reduced transportation costs due to the lower density of the additive compositions can also be beneficial to the environment, as less energy and / or CO₂ can be used or produced during transportation.

[0005] One aspect of the present invention concerns a dry particulate drilling fluid additive composition. The drilling fluid additive composition can contain a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and / or a fluid loss control additive. The viscosifier can contain a hectorite, montmorillonite, attapulgite, bentonite, or a combination thereof. ’The montmorillonite can contain a cationic surfactant treated montmorillonite clay. In certain embodiments, the montmorillonite contains a quaternary ammonium chloride treated montmorillonite clay. The hectorite can contain a cationic surfactant treated hectorite clay. In certain embodiments, the hectorite contains a quaternary ammonium salt treated hectorite clay. ’The attapulgite can contain an organophilic attapulgite clay. The bentonite can contain bentonite clay. The fluid loss control additive comprises asphaltite, a substituted styrene acrylate copolymer, or a combination thereof. The drilling fluid additive composition can contain 8 to 25 wt % of the tall oil fatty acid, 7 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 15 to 60 wt. % of the viscosifier, and 5 to 35 wt. % of the fluid loss control additive. The drilling fluid additive composition can optionally contain a wellbore strengthening agent.296204148.1 - 2 -The wellbore strengthening agent can contain a graphite, a sulfonated styrene butadiene copolymer, or a combination thereof. The drilling fluid additive composition can contain 8 to 25 wt. % of the tall oil fatty acid, 7 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 15 to 60 wt. % of the viscosifier, 5 to 35 wt. % of the fluid loss control additive, and optionally 2 to 20 wt. % of the wellbore strengthening agent. The drilling fluid additive composition can further contain a rheology modifier. The rheology modifier can be a polyamide based rheology modifier, anionic synthetic polymer based rheology modifier, alcohol adduct based rheology modifier, or a combination thereof. In certain embodiments, the anionic synthetic polymer based rheology modifier is an anionic synthetic polyacrylamide based rheology modifier. In certain embodiments, the alcohol adduct is an adduct of propylene oxide lauryl ether and naturally derived ethoxylated alcohol, and / or an adduct of non-ionic ethoxylated alcohol and lauryl alcohol.

[0006] The drilling fluid compositions of the present invention can be a dry blend of the tall oil fatty acid, talc, calcium hydroxide, viscosifier, fluid loss control additive, and optionally the wellbore strengthening agent and the rheology modifier. The dry blend composition can be a free flowing solid composition such as a particulate or powdered composition. Due to the hygroscopic nature of dry materials, the drilling fluid additive compositions of the present invention may include some moisture. In some aspect, thedrilling fluid additive composition can contain less than 10 wt. % water, preferably less than 5 wt. % water, or more preferably, less than 1 wt. % water or even more preferably 0 wt. % water.

[0007] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite such as a quaternary ammonium chloride treated montmorillonite, and asphaltite. In certain particular embodiments, the drilling fluid additive compositions contain 16 to 25 wt. % of the tali oil fatty acid, 15 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 20 to 35 wt. % of montmorillonite such as a quaternary ammonium chloride treated montmorillonite, and 15 to 30 wt. % of asphaltite.

[0008] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite such as a quaternary ammonium chloride treated montmorillonite, hectorite such as a quaternary ammonium salt treated hectorite, and asphaltite. In certain particular embodiments, the drilling fluid additive compositions contain 16 to 25 wt. % of the tall oil fatty acid, 15 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 15 to 30 wt. % of montmorillonite such as a quaternary ammonium296204148.1 - 3 -chloride treated montmorillonite, 10 to 20 wt. % of hectorite such as a quaternary ammonium salt treated hectorite, and 10 to 25 wt, % of asphaltite.

[0009] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite such as a quaternary ammonium chloride treated montmorillonite, and the substituted styrene acrylate copolymer. In certain particular embodiments, the drilling fluid additive compositions contain 16 to 25 wt. % of the tall oil fatty acid, 15 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 20 to 35 wt. % of the montmorillonite such as a quaternary'- ammonium chloride treated montmorillonite, and 15 to 30 wt. % of the substituted styrene acrylate copolymer. In certain embodiments, the substituted styrene acrylate copolymer can be pre-crosslinked.

[0010] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite such as a quaternary ammonium chloride treated montmorillonite, hectorite such as a quaternary ammonium salt treated hectorite, and the substituted styrene acrylate copolymer. In certain particular embodiments, the drilling fluid additive compositions contain 16 to 25 wt. % of the tall oil fatty acid, 15 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 15 to 30 wt. % of montmorillonite such as a quaternary ammonium chloride treated montmorillonite, 10 to 20 wt. % of the hectorite such as a quaternary ammonium salt treated hectorite, and 15 to 30 wt. % of the substituted styrene aery' late copolymer.

[0011] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite such as a quaternary'- ammonium chloride treated montmorillonite, hectorite such as a quaternary ammonium salt treated hectorite, attapulgite such as an organophilic attapulgite clay, and the substituted styrene acrylate copolymer. In certain particular embodiments, the drilling fluid additive compositions contain 16 to 25 wt. % of the tall oil fatty acid, 15 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 15 to 30 wt. % of montmorillonite such as a quaternary ammonium chloride treated montmorillonite, 10 to 20 wt. % of the hectorite such as a quaternary ammonium salt treated hectorite, 0.01 to 5 wt. % of the attapulgite such as an organophilic attapulgite clay, and 15 to 30 wt. % of the substituted styrene acrylate copolymer.

[0012] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid, talc, calcium hydroxide, bentonite, and the substituted styrene acrylate296204148.1 - 4 -copolymer. In certain particular’ embodiments, the drilling fluid additive compositions contain 11 to 22 wt. % of the tall oil fatty acid, 9 to 18 wt. % of talc, 10 to 15 wt. % of calcium hydroxide, 10 to 25 wt. % of bentonite, and 10 to 30 wt. % of the substituted styrene acrylate copolymer. In certain embodiments, the substituted styrene acrylate copolymer can be pre¬ crosslinked.

[0013] In certain embodiments, the drilling fluid additive compositions contain the tall oil fatty acid talc, calcium hydroxide, montmorillonite as a quaternary ammonium chloride treated montmorillonite, a substituted styrene acrylate copolymer, graphite, and the sulfonated styrene butadiene copolymer. In certain particular embodiments, the drilling fluid additive compositions contain 16 to 20 wt. % of the tall oil fatty acid, 15 to 20 wt. % of talc, 8 to 10 wt. % of calcium hy droxide, 20 to 25 wt. % of montmorillonite as a quaternary ammonium chloride treated montmorillonite, 15 to 20 wt. % of the substituted styrene acrylate copolymer, 3 to 5 wt. % of graphite, and 3 to 5 wt. % of the sulfonated styrene butadiene copolymer. In certain embodiments, the substituted styrene acrylate copolymer can be crosslinked.

[0014] Certain aspects are directed to a method for preparing the drilling fluid additive compositions of the present disclosure. The method can include dry blending the tall oil fatty acid, talc, calcium hydroxide, the viscosifier, the fluid loss control additive, and optionally the wellbore strengthening agent and the rheology modifier. In certain embodiments, the tall oil fatty acid, talc, calcium hydroxide, the viscosifier, the fluid loss control additive, and optionally the wellbore strengthening agent and the rheology modifier are dry blended together to form the drilling fluid additive compositions.

[0015] Certain aspects are directed to a drilling fluid. The drilling fluid can contain a drilling fluid additive composition described herein, and an oil. The oil can be diesel, a mineral oil, a synthetic oil, or a combination thereof. In certain embodiments, the oil is diesel. In certain embodiments, the oil is a mineral oil. In certain embodiments, the oil is a synthetic oil. The drilling fluid can further contain calcium chloride and barium sulfate. In certain embodiments, the drilling fluid contains 20 to 50 wt. % of the oil, 2 to 10 wt. % of a drilling fluid additive composition of the present invention, 0.5 to 10 wt. % of calcium chloride and 20 to 75 wt. % of barium sulfate. In certain particular embodiments, the drilling fluid contains, i) 40 to 50 wt. % of the oil; ii) 4 to 8 wt. %, of the drilling fluid additive composition; iii) 3 to 9 wt. %, of calcium chloride; and iv) 20 to 30 wt. %, of barium sulfate. In certain particular embodiments, the drilling fluid contains i) 20 to 35 wt. % of the oil; ii) 2 to 4 wt. %, of the drilling fluid296204148.1 - 5 -additive composition; iii) 0.5 to 2 wt. %, of calcium chloride; and iv) 65 to 75 wt. %, of barium sulfate. The drilling fluid can further contain water. The water can be dispersed in a continuous phase of the oil. The drilling fluid can have an oil-water ratio (OWR) of 70:30 to 98:2. The drilling fluid can have a mud weight (MW) of 5 to 20 pounds per gallon (ppg). In certain embodiments, the drilling fluid has a mud weight of 10 ppg. In certain embodiments, the drilling fluid has a mud weight of 16 ppg.

[0016] Certain aspects are directed to a method of drilling a wellbore into a subterranean well formation. The method can include providing a drilling fluid described herein, and / or a drilling fluid additive composition described herein into a drill pipe in the wellbore.

[0017] Other embodiments of the invention are discussed throughout this application. Any embodiment discussed with respect to one aspect of the invention applies to other aspects of the invention as well and vice versa. Each embodiment described herein is understood to be embodiments of the invention that are applicable to other aspects of the invention. It is contemplated that any embodiment or aspect discussed herein can be combined with other embodiments or aspects discussed herein and / or implemented with respect to any method or composition of the invention, and vice versa. Furthermore, compositions of the invention can be used to achieve methods of the invention.The following includes definitions of various terms and phrases used throughout this specification.

[0019] The terms “about” or “approximately” are defined as being close to as understood by one of ordinary skill in the art. In one non-limiting embodiment, the terms are defined to be within 10%, preferably within 5%, more preferably within 1%, and most preferably within 0.5%.

[0020] The terms “wt.%”, “vol.%”, or “mol.%” refers to a weight percentage of a component, a volume percentage of a component, or molar percentage of a component, respectively, based on the total weight, the total volume of material, or total moles, which includes the component. In a non-limiting example, 10 grams of component in 100 grams of the material is 10 wt.% of component.296204148.1 - 6 -

[0021] The terms “particulate” and “powder” can be used interchangeably. Particulate or powdered compositions can include separate particles of the additive compositions of the present invention. The separate particles can be free-flowing relative to one another (e.g., a composition can be transferred from one container to another by pouring the composition from one container to another).

[0022] rfhe term “substantially” and its variations are defined to include ranges within 10%, within 5%, within 1%, or within 0.5%.

[0023] The terms “removing”, “inhibiting”, “reducing”, “preventing” or “avoiding” or any variation of these terms, when used in the claims and / or the specification includes any measurable decrease or complete inhibition to achieve a desired result.

[0024] The term “effective,” as that term is used in the specification and / or claims, means adequate to accomplish a desired, expected, or intended result.

[0025] The use of the words “a” or “an” when used in conjunction with any of the terms “comprising,” “including,” “containing,” or “having” in the claims, or the specification, may mean “one,” but it is also consistent with the meaning of “one or more,” “at least one,” and “one or more than one.”

[0026] The phrase “and / or” means and or or. To illustrate, A, B, and / or C includes: A alone, B alone, C alone, a combination of A and B, a combination of A and C, a combination of B and C, or a combination of A, B, and C. In other words, “and / or” operates as an inclusive or.

[0027] The words “comprising” (and any form of comprising, such as “comprise” and “comprises”), “having” (and any form of having, such as “have” and “has”), “including” (and any form of including, such as “includes” and “include”) or “containing” (and any form of containing, such as “contains” and “contain”) are inclusive or open-ended and do not exclude additional, unrecited elements or method steps.

[0028] The processes and compositions of the present invention can “comprise,” “consist essentially of,” or “consist of’ particular ingredients, components, compositions, etc. disclosed throughout the specification. With respect to the transitional phrase “consisting essentially of,” in one non-limiting aspect, a basic and novel characteristic of the present296204148.1 - 7 -invention include a particulate drilling fluid additive composition containing a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and / or a fluid loss control additive.

[0029] Other objects, features and advantages of the present invention will become apparent from the following figures, detailed description, and examples. It should be understood, however, that the figures, detailed description, and examples, while indicating specific embodiments of the invention, are given by way of illustration only and are not meant to be limiting.. Additionally, it is contemplated that changes and modifications within the spirit and scope of the invention will become apparent to those skilled in the art from this detailed description. In further embodiments, features from specific embodiments may be combined with features from other embodiments. For example, features from one embodiment may be combined with features from any of the other embodiments. In further embodiments, additional features may be added to the specific embodiments described herein.BRIEF DESCRIPTION OF THE DRAWINGS

[0030] Advantages of the present invention may become apparent to those skilled in the art with the benefit of the following detailed description and upon reference to the accompanying drawings.

[0031] FIG. 1 is an illustration of one example of a particulate drilling fluid additive composition of the present invention.[00321 While the invention is susceptible to various modifications and alternative forms, specific embodiments thereof are shown by way of example in the drawings. ’The drawings may not be to scale.DETAILED DESCRIPTION OF THE INVENTION

[0033] Particulate free flowing drilling fluid additive compositions are disclosed. The drilling fluid additive compositions can contain a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and / or a fluid loss control additive. The drilling fluid additive compositions can have excellent emulsifier, viscosifier, wetting, and / or fluid loss control properties. The drilling fluid additive compositions can have powder flow properties, show no or relatively less clumping, and have good compaction properties. The drilling fluid additive compositions have relatively less transportation, storage and disposal costs. The mixing time of the drilling fluid additive compositions with oil to prepare drilling fluids is relatively low. The low mixing time296204148.1 - 8 -would reduce man hours at the drilling site thereby would decrease the cost of the drilling process, optimize liquid mud plant time, and reduce health, safety, and environmental (HSE) risks of the drilling process.

[0034] These and other non-limiting aspects of the present invention are discussed in further detail in the following sections.A. Drilling Fluid Additive Compositions

[0035] Certain aspects are directed to a drilling fluid additive composition. The drilling fluid additive composition can contain a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and a fluid loss control additive. In certain embodiments, the drilling fluid additive composition contains i) 8 wt, % to 25 w %, 8 wt, %, 9 wt. %, 10 wt. %, 11 wt, %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. % or any range or value therebetween of the tall oil fatty acid: ii) 7 wt. % to 20 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 wt. % to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 15 to 60 wt. %, 25 to 55 wt. %, 25 to 50 wt. %, 25 to 35 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, 35 wt. %, 36 wt. %, 37 wt. %, 38 wt. %, 39 wt. %, 40 wt. %, 41 wt. %, 42 wt. %, 43 wt. %, 44 wt. %, 45 wt. %, 46 wt. %, 47 wt. %, 48 wt. %, 49 wt. %, 50 wt. %, 51 wt. %, 52 wt. %, 53 wt. %, 54 wt. %, 55 wt. %, 56 wt. %, 57 wt. %, 58 wt. %, 59 wt. %, or 60 wt. % or any range or value therebetween of the viscosifier; v) 5 to 35 wt. %, 20 to 30 wt. %, 10 to 25 wt. %, 15 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt, %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt, %, 21 wt. %, 22 wt. %, 23 wt, %, 24 wt, %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt, %, 34 wt. %, or 35 wt. %, or any range or value therebetween of the fluid loss control additive, or any combination thereof. The drilling fluid additive composition can optionally contain a wellbore strengthening agent. In certain embodiments, the drilling fluid additive composition contains i) 8 wt. % to 25 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt, %, 24 wt. %, or 25 wt.296204148.1 - 9 -% or any range or value therebetween of the tall oil fatty acid; ii) 7 wt. % to 20 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 wt. % to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 15 to 60 wt. %, 25 to 55 wt. %, 25 to 50 wt. %, 25 to 35 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt.25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, 35 wt. %, 36 wt. %, 37 wt. %, 38 wt. %, 39 wt. %, 40 wt. %, 41 wt. %, 42 wt. %, 43 wt. %, 44 wt. %, 45 wt. %, 46 wt. %, 47 wt. %, 48 wt. % 49 wt. %, 50 wt. %, 51 wt. %, 52 wt. %, 53 wt. %, 54 wt. %, 55 wt. %, 56 wt. %, 57 wt. %, 58 wt. %, 59 wt. %, or 60 wt. % or any range or value therebetween of the viscosifier; v) 5 to 35 wt. %, 20 to 30 wt. %, 10 to 25 wt. %, 15 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, or 35 wt. %, or any range or value therebetween of the fluid loss control additive; vi) 2 wt. % to 20 wt. %, 4 wt. % to 15 wt. %, 2 wt. %, 3 wt. %, 4 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of the wellbore strengthening agent; or any combination thereof. The drilling fluid additive composition can further contain a rheology modifier. The rheology modifier can be a polyamide based rheology modifier, anionic synthetic polymer based rheology modifier, alcohol adduct based rheology modifier or a combination thereof. In certain embodiments, the anionic synthetic polymer based rheology modifier is an anionic synthetic polyacrylamide based rheology modifier. In certain embodiments, the alcohol adduct is an adduct of propylene oxide lauryl ether and naturally derived ethoxylated alcohol, and / or an adduct of non-ionic ethoxylated alcohol and lauryl alcohol.

[0036] The tall oil fatty acid can contain one or more long chain carboxylic acids obtained from a kraft process of wood pulp manufacture. In certain embodiments, the tall oil fatty acid contains one or more unsaturated long chain carboxylic acids obtained from a kraft process of wood pulp manufacture. In certain embodiments, the tall oil fatty acid can be a reaction product of fatty acid and tall oil. In certain embodiments, the tall oil fatty acid contains296204148.1 - 10-the chemical with the CAS No. 68990-47-6. Commercially available tall oil fatty acids that can be used include tall oil fatty acids found in DFE4144 sold by Baker Hughes.

[0037] The viscosifier can contain an organophilic clay and / or non-organophilic clay. The organophilic clay can contain a silicate mineral clay treated with a cationic surfactant. The silicate mineral can contain silicate groups and one or more metals selected from lithium, sodium, calcium, aluminum, and magnesium. Treating the clay with the cationic surfactant can make the clay more oil dispersible. In certain embodiments, the cationic surfactant is a quaternary ammonium salt. In certain embodiments, the quaternary ammonium salt is a quaternary ammonium chloride. Treating the silicate mineral clay with the quaternary ammonium salt can replace some of the metals in the silicate material with ammonium. In certain embodiments, the viscosifier contains hectorite, montmorillonite, attapulgite, bentonite, or a combination thereof. In certain embodiments, the viscosifier contains a cationic surfactant treated hectorite, cationic surfactant treated montmorillonite, cationic surfactant treated attapulgite, cationic surfactant treated bentonite, or a combination thereof. In certain embodiments, the viscosifier contains a quaternary ammonium salt treated hectorite, quaternary ammonium chloride treated montmorillonite, organophilic attapulgite clay, bentonite clay, or a combination thereof. The bentonite clay can be American Petroleum Institute (. API) grade bentonite clay. Commercially available viscosifiers that can be used include CARBO-GEL II, CARBOGEL, MAGMA-Gel SE, and MILGEL sold by Baker Hughes.

[0038] Idle fluid loss control additive comprises asphaltite and / or a substituted styrene acrylate copolymer, or a combination thereof. The substituted styrene acrylate copolymer can contain substituted styrene monomers and acrylate monomers. In certain embodiments, the substituted styrene acrylate copolymer can be pre-crosslinked. Commercially available substituted styrene acrylate copolymer that can be used includes DELTA-FL HT and / or DELTA-FL ST sold by Baker Hughes. Asphaltite is a naturally occurring hydrocarbon deposit and can contain asphaltenes and nitrogen compounds. The composition of asphaltite can vary based on its source. Asphaltite is also known in the field as uintahite, asphaltum, gilsonite, oil sands, bitumen or asphalt. Commercially available asphaltite that can be used includes Carbo-Trol 375 sold by Baker Hughes.

[0039] The wellbore strengthening agent comprises graphite, a sulfonated styrene butadiene copolymer, or a combination thereof. Commercially available graphite that can be296204148.1 - 11 -used includes LC-Lube sold by Baker Hughes. The sulfonated styrene butadiene copolymer can contain sulfonated styrene monomers and butadiene monomers. Commercially available sulfonated styrene butadiene copolymer that can be used includes NANO-SHIELD sold by Baker Hughes.

[0040] In certain embodiments, the drilling fluid additive composition can contain the tail oil fatty acid, talc, calcium hydroxide, montmorillonite, and asphaltite. In certain embodiments, the drilling fluid additive composition can contain i) 16 to 25 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wl. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. % or any range or value therebetween of the tall oil fatty acid; ii) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 20 to 35 wt. % 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 2.7 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, or 35 wt. %, or any range or value therebetween of montmorillonite; and v) 15 to 30 wt. % 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt %, 29 wt. %, or 30 wt. %, or any range or value therebetween of asphaltite. The montmorillonite can contain a quaternary ammonium chloride salt treated montmorillonite. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier.

[0041] In certain embodiments, the drilling fluid additive composition can contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite, hectorite and asphaltite. In certain embodiments, the drilling fluid additive composition can contain i) 16 to 25 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. % or any range or value therebetween of the tall oil fatty acid; ii) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of montmorillonite; v) 10 to 20 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17296204148.1 - 12 -wt. %, 18 wt. %, 19 wt. %, or 20 wt. %, or any range or value therebetween of hectorite: and vi) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wL %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of asphaltite. The montmorillonite can contain a quaternary ammonium chloride treated montmorillonite. The hectorite can contain a quaternary ammonium salt treated hectorite. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier.

[0042] In certain embodiments, the drilling fluid additive composition can contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite, and substituted styrene acrylate copolymer. In certain embodiments, the drilling fluid additive composition can contain i) 16 to 25 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. % or any range or value therebetween of the tall oil fatty acid; ii) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 20 to 35 wt. % 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, or 35 wt. %, or any range or value therebetween of montmorillonite; and v) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of substituted styrene acrylate copolymer. The montmorillonite can contain quaternary ammonium chloride treated montmorillonite. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier. In certain embodiments, the substituted styrene acrylate copolymer can be pre-crosslinked.

[0043] In certain embodiments, the drilling fluid additive composition can contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite, hectorite, attapulgite and the substituted styrene acr late-copolymer. In certain embodiments, the drilling fluid additive composition can contain i) 16 to 25 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. % or any range or value therebetween of the tall oil fatty acid: ii) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %,296204148.1 - 13 -8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. % 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 2.7 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of montmorillonite; v) 10 to 20 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. %, or any range or value therebetween of hectorite; and vi) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of the substituted styrene acrylate-copolymer. The montmorillonite can contain a quaternary ammonium chloride treated montmorillonite. The hectorite can contain a quaternary ammonium salt treated hectorite. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier.

[0044] In certain embodiments, the drilling fluid additive composition can contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite, hectorite, attapulgite and the substituted styrene acrylate-copolymer. In certain embodiments, the drilling fluid additive composition can contain i) 16 to 25 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. % or any range or value therebetween of the tall oil fatty acid; ii) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc; iii) 5 to 20 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of calcium hydroxide; iv) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of montmorillonite; v) 10 to 20 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. %, or any range or value therebetween of hectorite; vi) 0.01 to 5 wt. %, 0.01 wt. %, 0.05 wt. %, 0.1 wt. %, 0.5 wt. %, 1 wt. %, 2 wt. %, 3 wt. %, 4 wt. %, or 5 wt. %, or any range or value therebetween of attapulgite; and vii) 15 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of the substituted styrene acrylate-copolymer. The montmorillonite can contain a quaternary ammonium chloride treated montmorillonite. The hectorite can contain a quaternary' ammonium salt treated296204148.1 - 14 -hectorite. The attapulgite can contain organophilic attapulgite clay. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier.

[0045] In certain embodiments, the drilling fluid additive composition can contain the tall oil fatty acid, talc, calcium hydroxide, bentonite, and substituted styrene acrylate copolymer. In certain embodiments, the drilling fluid additive composition can contain i) 11 to 22 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, or 22 wt. % or any range or value therebetween of the tall oil fatty acid; ii) 9 to 18 wt. %, 9 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, or 18 wt. % or any range or value therebetween of talc; iii) 10 to 15 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, or 15 wt. % or any range or value therebetween of calcium hydroxide; iv) 10 to 25 wt. %, 10 wt. %, 11 wt. %, 12 wt. %, 13 wt. %, 14 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. %, or any range or value therebetween of bentonite; and v) 10 to 30 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, or 30 wt. %, or any range or value therebetween of substituted styrene acrylate copolymer. ’The bentonite can contain API grade bentonite clay. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier. In certain embodiments, the substituted styrene acrylate copolymer can be pre-crosslinked.

[0046] In certain embodiments, the drilling fluid additive composition can contain the tall oil fatty acid, talc, calcium hydroxide, montmorillonite, substituted styrene acrylate copolymer, graphite, and the sulfonated styrene butadiene copolymer. In certain embodiments, the drilling fluid additive composition can contain i) 16 to 20 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 220 wt. % or any range or value therebetween of the tall oil fatty acid; ii) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of talc: iii) 8 to 10 wt. %, 8 wt. %, 9 wt. %, or 10 wt. % or any range or value therebetween of calcium hydroxide; iv) 20 to 25 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, or 25 wt. %, or any range or value therebetween of montmorillonite; v) 15 to 20 wt. %, 15 wt. %, 16 wt. %, 17 wt. %, 18 wt. %, 19 wt. %, or 20 wt. % or any range or value therebetween of substituted styrene acrylate copolymer; vi) 3 to 5 wt, %, 3 wt. %, 4 wt. %, or 5 wt. % or any range or value therebetween of graphite; and vii) 3 to 5 wt. %, 3 wt. %, 4 wt. %, or 5 wt. % or any range or value therebetween of the sulfonated styrene butadiene296204148.1 - 15 -copolymer. The montmorillonite can contain a quaternary ammonium chloride treated montmorillonite. The drilling fluid additive composition described in this paragraph can optionally contain a rheology modifier. In certain embodiments, the substituted styrene acrylate copolymer can be pre-crosslinked.

[0047] The drilling fluid additive composition can be a dry blend of the tall oil fatty acid, talc, calcium hydroxide, viscosifier, fluid loss control additive, and optionally the wellbore strengthening agent and the rheology modifier. The dry blend composition can be a free flowing solid composition. The drilling fluid additive composition can have a desired particle size, powder flowability and compaction properties. FIG. 1 shows a picture of a drilling fluid additive composition according to one example of the present disclosure. As can be seen from FIG. 1 the drilling fluid additive composition of the present disclosure has powdered texture.

[0048] The drilling fluid additive composition can contain less than 10 wt. % water, preferably less than 5 wt. % water, or more preferably, less than 1 wt. % water or even more preferably 0 wt. % water. The drilling fluid additive composition at room temperature and pressure can contain less than 10 wt. % of liquid, preferably less than 5 wt. % of liquid, or more preferably less than 1 wt. % of liquid or even more preferably 0 wt. % of liquid.

[0049] The drilling fluid additive composition can be prepared by dry blending the tall oil fatty acid, talc, calcium hydroxide, the viscosifier, the fluid loss control additive, and optionally the wellbore strengthening agent and the rheology modifier. In certain embodiments, the tall oil fatty acid, talc, calcium hydroxide, the viscosifier, the fluid loss control additive, and optionally the wellbore strengthening agent and the rheology modifier are dry blended together to form the drilling fluid additive composition. The composition can be grinded by any suitable methods to obtain particles of desired size.B. Drilling Fluid Compositions

[0050] Certain aspects are directed to a drilling fluid. The drilling fluid can contain a drilling fluid additive composition described herein, and an oil. The oil can contain diesel, kerosene, fuel oil, crude oil, mineral oil, a synthetic oil, or a combination thereof. In certain embodiments, the oil contains diesel. In certain embodiments, the oil contains a mineral oil. In certain embodiments, the oil contains a synthetic oil. The drilling fluid can further contain calcium chloride and barium sulfate. In certain embodiments, the drilling fluid contains i) 20296204148.1 - 16 -to 50 wt. %, 25 to 35 wt. %, 40 to 50 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, 35 wt. %, 36 wt. %, 37 wt. %, 38 wt. %, 39 wt. %, 40 wt. %, 41 wt. %, 42 wt. %, 43 wt. %, 44 wt. %, 45 wt. %, 46 wt. %, 47 wt. %, 48 wt. %, 49 wt. %, or 50 wt. % or any range or value therebetween of the oil: ii) 2 to 10 wt. %, 2 to 6 wt. %, 4 to 8 wt. %, 2 wt. %, 3 wt. %, 4 wt. %, 5 wt. %, 6 wt. %, 7 wt. %, 8 wt. %, 9 wt. %, or 10 wt. % or any range or value therebetween of the drilling fluid additive composition; iii) 0.5 to 10 wt. %, 0.5 to 2 wt. %, 3 to 9 wt. % 0.5 wt. %, 1 wt. %, 2 wt. %, 3 wt. %, 4 wt. %, 5 wt. % 6 wt. %, 7 wt. % 8 wt. %, 9 wt. %, or 10 wt. % or any range or value therebetween of calcium chloride; and iv) 20 to 75 wt. %, 20 to 30 wt. %, 65 to 75 wt. %, 20 wt. %, 21 wt. %, 22 wt. %, 23 wt. %, 24 wt. %, 25 wt. %, 26 wt. %, 27 wt. %, 28 wt. %, 29 wt. %, 30 wt. %, 31 wt. %, 32 wt. %, 33 wt. %, 34 wt. %, 35 wt. %, 36 wt. %, 37 wt. %, 38 wt. %, 39 wt. %, 40 wt. %, 41 wt. %, 42 wt. %, 43 wt. %, 44 wt. %, 45 wt. %, 46 wt. %, 47 wt. %, 48 wt. %, 49 wt. %, 50 wt. %, 51 wt. %, 52 wt. %, 53 wt. %, 54 wt. %, 55 wt. %, 56 wt. %, 57 wt. %, 58 wt. %, 59 wt. %, 60 wt. %, 61 wt. %, 62 wt. %, 63 wt. %, 64 wt. %, 65 wt. %, 66 wt. %, 67 wt. %, 68 wt. %, 69 wt. %, 70 wt. %, 71 wt. %, 72 wt. %, 73 wt. %, 74 wt. %, or 75 wt. % or any range or value therebetween of barium sulfate.

[0051] In certain embodiments, the drilling fluid contains i) 40 to 50 wt. % of the oil; ii) 4 to 8 wt. %, of the drilling fluid additive composition; iii) 3 to 9 wt. %, of calcium chloride; and iv) 20 to 30 wt. %, of barium sulfate. In certain embodiments, the drilling fluid contains i) 25 to 35 wt. % of the oil; ii) 2 to 4 wt. %, of the drilling fluid additive composition; iii) 0.5 to 2 wt. %, of calcium chloride; and iv) 65 to 75 wt. %, of barium sulfate.

[0052] In certain embodiments, the drilling fluid contains i) 40 to 50 wt. % of the oil; ii) 4 to 8 wt. %, of the drilling fluid additive composition; iii) 3 to 9 wt. %, of calcium chloride; and iv) 20 to 30 wt. %, of barium sulfate, where the drilling fluid additive composition contains a) 16 to 25 wt. % of the tall oil fatty acid, b) 15 to 20 wt. % of talc, c) 5 to 20 wt. % of calcium hydroxide, d) 20 to 35 wt. % of montmorillonite, and e) 15 to 30 wt. % of asphaltite. The wt. % of the drilling fluid are based on the total weight of the drilling fluid, and the wt. % of the drilling fluid additive composition are based on the total weight of the drilling fluid additive composition.

[0053] In certain embodiments, the drilling fluid contains i) 40 to 50 wt. % of the oil; ii) 4 to 8 wt. %, of the drilling fluid additi ve composition; iii) 3 to 9 wt. %, of calcium chloride; and iv) 20 to 30 wt. %, of barium sulfate, where the drilling fluid additive composition contains296204148.1 - 17 -a) 16 to 25 wt. % of the tall oil fatty acid, b) 15 to 20 wt. % of talc, c) 5 to 20 wt. % of calcium hydroxide, d) 15 to 30 wt. % of montmorillonite, e) 10 to 20 wt. % of hectorite, and f) 10 to 25 wt. % of asphaltite. The wt. % of the drilling fluid are based on the total weight of the drilling fluid, and the wt. % of the drilling fluid additive composition are based on the total weight of the drilling fluid additive com position.

[0054] In certain embodiments, the drilling fluid contains i) 25 to 35 wt. % of the oil; ii) 2 to 4 wt. %, of the drilling fluid additive composition: Hi) 0.5 to 2 wt. %, of calcium chloride; and iv) 65 to 75 wt. %, of barium sulfate, where the drilling fluid additive composition contains a) 16 to 25 wt. % of the tall oil fatty acid, b) 15 to 20 wt. % of talc, c) 5 to 20 wt. % of calcium hydroxide, d) 15 to 30 wt. % of montmorillonite, e) 10 to 20 wt. % of hectorite, and f) 10 to 25 wt. % of asphaltite. The wt. % of the drilling fluid are based on the total weight of the drilling fluid, and the wt. % of the drilling fluid additive composition are based on the total weight of the drilling fluid additive composition.

[0055] In certain embodiments, the drilling fluid can further contain water. The water can be dispersed in a continuous phase of the oil. The drilling fluid can have an oil-water ratio (OWR) of 70:30 to 98:2, 70:30, 72:28, 74:26, 75:25, 76:24, 78:22, 80:20, 82:18, 84:16, 86:14, 88:12, 90:10, 92:8, 94:6, 95:5, 96:4, or 98:22, or any range or value therebetween.

[0056] The drilling fluid can have a mud weight (MW) of 5 to 20 pounds per gallon (ppg), 5 ppg, 6 ppg, 7 ppg, 8 ppg, 9 ppg, 10 ppg, 11 ppg, 12 ppg, 13 ppg, 14 ppg, 15 ppg, 16 ppg, 17 ppg, 18 ppg, 19 ppg, or 20 ppg, or any range or value therebetween. In certain embodiments, the drilling fluid has a mud weight of 10 ppg. In certain embodiments, the drilling fluid has a mud weight of 16 ppg.

[0057] The drilling fluid can have a plastic viscosity of 10 to 16 centipoise (cP), 10 cP, 11 cP, 12 cP, 13 cP, 14 cP, 15 cP or 16 cP, or any range or value therebetween at 150 °F, where the plastic viscosity is measured using the equation 1.Plastic viscosity (cP) - 600 rpm SS - 300 rpm SS > (1)

[0058] The drilling fluid can have a yield point of 7 to 13 lb / 100 ft, 7 lb / 100 ft, 8 lb / 100 ft, 9 lb / 100 ft, 10 lb / 100 ft, 11 lb / 100 ft, 12 lb / 100 ft or 13 lb / 100 ft or any range or value296204148.1 - 18 -therebetween at 150 °F, where the yield point is measured using the equation 2, and plastic viscosity is measured using the equation 1.Yield point (lb / 100 ft) = 300 rpm shear stress (SS) - Plastic viscosity (cP). (2)

[0059] Yield point and plastic viscosity are measure of viscosity characteristics of the drilling fluid. The shear stress of the drilling fluid, as 600 rpm and 300 rpm at a desired temperature, such as 150 °F, can be measured using American Petroleum Institute Recommended Practices, APIRP 13B-2, API RP 13D, API RP 131 2023.

[0060] The drilling fluid can have a high temperature high pressure (HTHP) fluid loss < 10 ml, preferably < 6 ml, more preferably < 4 ml after hot rolling at 300 °F. The HTHP fluid loss can be measured using API bulletin RP 131, 2009, at a desired temperature, such as at 300 °F, and 500 psi differential pressure, using a 175 mL, 4-unit filter press with regulators and tempera ture controllers.

[0061] The drilling fluid can have an electrical stability of 400 V to 2000 V, 400, 500, 600, 700, 800, 900, 1000, 1100, 1200, 1300, 1400, 1500, 1600, 1700, 1800, 1900 or 2000 V or any range or value therebetween at 120 °F. The electrical stability of the drilling fluid can be measured using API standard API RP13 B-2[00621 The drilling fluid can be stable up to 275 °F, preferably up to 300 °F, still more preferably up to 325 °F, still even more preferably up to 350 °F.

[0063] The drilling fluid can be prepared by contacting the drilling fluid additive composition described herein with the oil. The drilling fluid additive composition can be added to the oil in in one application to prepare the drilling fluid.C. Method of Using the Drilling Fluid Composition

[0064] Certain aspects are directed to a method for using a drilling fluid described herein. The drilling fluid can be used to drill a wellbore into a subterranean well formation. The drilling fluid can be circulated to the wellbore through a drill string. The drilling fluid might control the sub surface pressure, and maintain chemical and mechanical stability of the well bore. The drill string can contain a drill bit, and the drilling fluid might lubricate and control temperature of the drill string and / or the drill bit during the drilling process. The drilling fluid might provide hydraulic pressure to the drill bit and / or other drilling tools. The drilling296204148.1 - 19 -fluid can come out of the drill bit, and can be circulated back to the surface. ’The fluid circulated back to the surface might remove drill cutings from the wellbore.EXAMPLES

[0065] The present invention will be described in greater detail by way of specific examples. The following examples are offered for illustrative purposes only, and are not intended to limit the invention in any manner. Those of skill in the art will readily recognize a variety of noncritical parameters which can be changed or modified to yield essentially the same results.Example 1Drilling fluids and their properties

[0066] Three drilling fluids containing drilling fluid additive compositions of the present invention were prepared. All of the drilling fluid additive compositions were in particulate form (see FIG. 1 as an illustration). Table 1 provides the compositions of the drilling fluids. Table 1 also provides the testing information for the drilling fluids. Table 2 provides the compositions of the drilling fluid additive compositions that were used to prepare the drilling fluids. Table 3 shows the electrical stability, rheology, HTHP fluid loss properties of the drilling fluids.Table 1: Drilling fluidsFluid 1 Fluid 2 Fluid 3 pbb Wt. % pbb Wt. % pbb Wt. % Diesel 190.8 45% 190.8 45% 187.16 30% CaCI2(25%) 100.95 24% 100.95 24% 15.63 3% MILBAR 103.25 25% 103.25 25% 444.2 72% Drilling fluid additive25 6% - - - - composition 1Drilling fluid additive composition 2 - - 25 6% 25 4% Testing InformationFluid Density / Mud weight (Calculated) 10ppg(1.2 s.g.) 10ppg(1.2 s.g.) 16ppg(1.9s.g) OikWater Ratio (OWR) (Calculated) 75 / 25 75 / 25 95 / 5 Salinity (Calculated) 25.0 25.0 25.0 Ageing Cell Pressure 100 100 100296204148.1 - 20-Table 2: Drilling Fluid Additive CompositionsDrilling fluid additive Drilling fluid additive composition 1 composition 2 Tall oil fatty acid (wt.%) 20 20Talc (wt. %) 16 16Calcium hydroxide (wt. %) 12 12Quaternary ammonium chloride treated28 15-30 montmorillonite (wt. %)Quaternary ammonium salt treated10-20hectorite (wt. %)Asphaltite (wt. %) 24 10-25

[0067] The shear stress of the drilling fluids were measured using American Petroleum Institute Recommended Practices, API RP 13B-2, API RP 13D, API RP 13I 2023. Sheer stress at 600, 300, 200, 100, 6, at 3 RPM as well as the 10-second, 10-minute, and 30-minute gel strengths were measured before and after hot rolling at the indicated temperature using OFITE’s Model 900 or 800 or FANN 35A viscometer. The hot rolling temperatures are provided in Table 3. The plastic viscosity and yield point were calculated based on the equations 1 and 2 respectively. Electrical stability of the drilling fluids were measured at 120 °F using a Emulsion Stability Tester or Electrical Stability Meters FANN Model 23E. HTHP fluid loss before and after hot rolling at the indicated temperatures were measured with a 500-psi differential using a 175 mL, 4-unit HPHT filter press FANN 175 / 500 model filter press. Fluid loss and cake thickness were recorded, and any water present in the filtrate was noted. In each case no or trace water in filtrate were observed.296204148.1 - 21 -Table 3:Fluid 1 Fluid 2 Fluid 3 AgeingINITIA HR@ HR@30 HR@32 INITIA HR@15 HR@30 HR@32 INITIA HR@15 HR@30 temperaturL 150 0 0 L 0 0 5 L 0 0 eElectricalStability @ 498.0 623.0 594.0 498.0 1310.0 1552.0 1236.0 >2000 1306.0 1472.0 120°F600 RPM 51 55 45 39 53 54 42 100.0 83 73 69 300 RPM 31 34 24 21 30 31 25 67.0 51 44 39 200 RPM 24 27 18 14 22 22 18 55.0 42 34 30 100 RPM 18 21 12 10 14 15 13 44.0 32 25 22 6 RPM 12 13 6 5 9 9 7 29.0 20 14 10 3 RPM 11 11 5 4 8 8 6 28.0 19 13 9 Plastic20 21 21 18 23 23 17 33 32 29 30 ViscosityYield Point 11 13 3 3 7 8 8 34 19 15 9 10 Second16 17 7 7 12 12 9 32.0 22 19 12 Gel10 Minute21 23 9 9 14 15 14 36.0 28 22 19 Gel30 Minute22 24 9 10 15 15 14 38.0 29 22 22 GelYS 10 9 4 3 7 7 5 27 18 12 8 HTHP@300 °F,API- adisk 3.2 2.8 5.6 10.8 2.6 2.5 5.0 4.0 3.4 (Actual)(DOUBLED)Water In0 0 Trace trace 0 0 0.0 0.0 0 the filtrateHR = Hot rolling

[0068] Table 3 shows drilling fluids containing the drilling fluid additive compositions of the current disclosure can have desired yield point, plastic viscosity, electric stability, and high temperature high pressure (HTHP) fluid loss properties.296204148.1 - 22 -***

[0069] . Although embodiments of the present application and their advantages have been described in detail, it should be understood that various changes, substitutions, and alterations can be made herein without departing from the spirit and scope of the embodiments as defined by the appended claims. Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, composition of matter, means, methods and steps described in the specification. As one of ordinary skill in the art will readily appreciate from the above disclosure, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein can be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.296204148.1 - 23 -

Claims

CLAIMS1. A drilling fluid additive composition, the composition comprising a tall oil fatty acid, talc, calcium hydroxide, a viscosifier, and a fluid loss control additive.

2. The drilling fluid additive composition of claim 1, wherein the viscosifier comprises a hectorite, montmorillonite, attapulgite, bentonite, or a combination thereof.

3. The drilling fluid additive composition of claim 1 or 2, wherein the fluid loss control additive comprises asphaltite, a substituted styrene acrylate copolymer, or a combination thereof.

4. The drilling fluid additive composition of any one of claims 1 to 3, comprising 8 to 25 wt. % of the tall oil fatty acid, 7 to 20 wt. % of talc, 5 to 20 wt. % of calcium hydroxide, 15 to 60 wt. % of the viscosifier, and 5 to 35 wt. % of the fluid loss control additive.

5. The drilling fluid additive composition of any one of claims 1 to 4, further comprising a wellbore strengthening agent.

6. The drilling fluid additive composition of claim 5, wherein the wellbore strengthening agent comprises graphite, a sulfonated styrene butadiene copolymer, or a combination thereof.

7. The drilling fluid additive composition of claim 5 or 6, comprising 2 to 20 wt. % of the wellbore strengthening agent.

8. The drilling fluid additive composition of any one of claims 1 to 7, wherein the composition is a dry blend of the tall oil fatty acid, talc, calcium hydroxide, viscosifier, fluid loss control additive, and optionally the wellbore strengthening agent.

9. The drilling fluid additive composition of any one of claims 1 to 8, wherein the composition comprises less than 10 wt. % water, preferably less than 5 wt. % water, or more preferably, less than 1 wt. % water or even more preferably 0 wt. % water.

10. A method of preparing the drilling fluid additive composition of any one of claims 1 to 9, the method comprising dry blending the tall oil fatty acid, talc, calcium hydroxide, the viscosifier, the fluid loss control additive, and optionally the wellbore strengthening agent.

11. A drilling fluid comprising the drilling fluid additive composition of any one of claims 1 to 10 and an oil.296204148.1 - 24 -12. The drilling fluid of claim 11, wherein the oil is diesel, a mineral oil, a synthetic oil, or a combination thereof.

13. The drilling fluid of claim 11 or 12, further comprising calcium chloride and barium sulfate.

14. The drilling fluid of any one of claims 11 to 13, comprising 20 to 50 wt. % of the oil, 2 to 10 wt. % of the composition of any one of claims 1 to 20, 0.5 to 10 wt. % of calcium chloride and 20 to 75 wt. % of barium sulfate.

15. A method of drilling a wellbore into a subterranean well formation, the method comprising providing the drilling fluid of any one of claims 11 to 14 and / or the drilling fluid additive composition of any one of claims 1 to 10 into a drill pipe in the wellbore.296204148.1 - 25 -

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