Doc Code: TR.PROV
`Document Description: Provisional Cover Sheet (SB16)
`
`PTO/SB/16 (02-18)
`Approved for use through 11/30/2020. 0MB 0651-0032
`U.S. Patent and Trademark Office: U.S. DEPARTMENT OF COMMERCE
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`Provisional Application for Patent Cover Sheet
`This is a request for filing a PROVISIONAL APPLICATION FOR PATENT under 37 CFR 1.53(c)
`
`lnventor(s)
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`Inventor 1
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`Given Name
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`Middle Name
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`Family Name
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`Fichard
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`Inventor 2
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`I
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`~hristie
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`Given Name
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`Middle Name
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`Family Name
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`f1orence
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`I
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`Finet
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`City
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`I Fugar Land
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`City
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`I Fugar Land
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`State
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`lfx
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`State
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`lfx
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`All Inventors Must Be Listed -Additional Inventor Information blocks may be
`generated within this form by selecting the Add button.
`
`Title of Invention
`
`~oordinated Pumping Operations
`
`Attorney Docket Number (if applicable)
`
`IIS19.0176-US-PSP
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`Correspondence Address
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`Direct all correspondence to (select one):
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`@ The address corresponding to Customer Number
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`0 Firm or Individual Name
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`Customer Number
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`127452
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`I Remove I
`Country i
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`I ~s
`I Remove I
`Country i
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`I ~s
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`I Add
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`I
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`I
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`I
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`I
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`The invention was made by an agency of the United States Government or under a contract with an agency of the United
`States Government.
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`• No .
`
`Yes, the invention was made by an agency of the United States Government. The U.S. Government agency name is:
`Yes, the invention was under a contract with an agency of the United States Government. The name of the U.S.
`Government agency and Government contract number are:
`
`EFS - Web 1.0.2
`
`IWS EXHIBIT 1019
`
`EX_1019_001
`
`

`

`Doc Code: TR.PROV
`Document Description: Provisional Cover Sheet (SB16)
`
`PTO/SB/16 (02-18)
`Approved for use through 11/30/2020. 0MB 0651-0032
`U.S. Patent and Trademark Office: U.S. DEPARTMENT OF COMMERCE
`Under the Paperwork Reduction Act of 1995, no persons are required to respond to a collection of information unless it displays a valid 0MB control number
`
`Entity Status
`Applicant asserts small entity status under 37 CFR 1.27 or applicant certifies micro entity status under 37 CFR 1.29
`
`0 Applicant asserts small entity status under 37 CFR 1.27
`0 Applicant certifies micro entity status under 37 CFR 1.29. Applicant must attach form PTO/SB/15A or B or equivalent.
`@ No
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`Signature
`
`Please see 37 CFR 1.4(d) for the form of the signature.
`
`I Date (YYYY-MM-DD)
`I Registration Number
`
`(If appropriate)
`
`~019-07-24
`
`~2001
`
`I
`I
`
`This collection of information is required by 37 CFR 1.51. The information is required to obtain or retain a benefit by the public which is to
`file (and by the USPTO to process) an application. Confidentiality is governed by 35 U.S.C. 122 and 37 CFR 1.11 and 1.14. This collection
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`form can only be used when in conjunction with EFS-Web. If this form is mailed to the USPTO, it may cause delays in handling
`the provisional application.
`
`Signature
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`First Name
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`f Cathy Hewitt/
`
`Eathy
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`I Last Name
`
`~ewitt
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`EFS - Web 1.0.2
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`IWS EXHIBIT 1019
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`EX_1019_002
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`

`

`Privacy Act Statement
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`enforcement agency, if the USPTO becomes aware of a violation or potential violation of law or regulation.
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`IWS EXHIBIT 1019
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`EX_1019_003
`
`

`

`Attorney Docket No. 1S19.0176-US-PSP
`Coordinated Pumping Operations
`
`Customer No. 27452
`
`Background of the Disclosure
`
`[0001]
`
`A wellbore stimulation job utilizes several well service systems at a wellsite. A
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`stimulation job for a horizontal wellbore may include dividing the wellbore into numerous
`
`individual operations or stages. For example, a wellbore stimulation job may be divided into
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`sixty or more individual stimulation operations or stages. The process utilizes individual
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`pumping and wireline operations (e.g., pump-down and perforating operations) between each
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`stimulation stage (e.g., hydraulic fracturing) to isolate the well bore and perforate a casing.
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`Such pumping and wireline operations are also coordinated with wellhead fluid control
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`valves associated with the wellbore.
`
`[0002]
`
`The above-described operations and systems utilize different well services that are
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`executed independently, each focusing on different objectives without knowledge or
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`consideration of status of other well services. For example, each well service is conducted by
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`corresponding equipment that is manually coordinated by different companies and/or crews,
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`with little to no automation or communication between the well services. Coordination
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`across these well services may include implementing check lists, manual hands-signals, and
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`voice communication via radios in order to execute each consecutive well service. A
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`completion job becomes even more challenging as multi-well pads are constructed to permit
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`multiple well bores to be stimulated in parallel with the same suite of well servicing
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`equipment. Lack of coordination and communication between the well services results in
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`inefficiencies, resulting in just 12-16 hours of active pumping per day.
`
`Summary of the Disclosure
`
`[0003]
`
`This summary is provided to introduce a selection of concepts that are further
`
`described below in the detailed description. This summary is not intended to identify
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`indispensable features of the claimed subject matter, nor is it intended for use as an aid in
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`limiting the scope of the claimed subject matter.
`
`[0004]
`
`The present disclosure introduces an apparatus including a treatment fluid system,
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`a pump-down system, a fluid valve system, and a controller. The treatment fluid system is
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`operable to pump a treatment fluid into a wellbore extending into a subterranean formation
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`from a surface of an oil/gas wellsite. The pump-down system is operable to pump a pump(cid:173)
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`down fluid into the well bore to convey a perforating tool within the well bore. The fluid
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`valve system is operable to selectively fluidly connect and disconnect the treatment fluid
`
`1
`
`IWS EXHIBIT 1019
`
`EX_1019_004
`
`

`

`Attorney Docket No. 1S19.0176-US-PSP
`Customer No. 27452
`system and pump-down system with and from the wellbore. The controller includes a
`
`processor and a memory storing a computer program code, and is communicatively
`
`connected with the treatment fluid system, the pump-down system, and the fluid valve
`
`system The controller is operable to monitor operational status of the treatment fluid system,
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`the pump-down system, and the fluid valve system The controller is also operable to control
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`operations of the treatment fluid system, the pump-down system, and the fluid valve system
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`based on the operational status of the treatment fluid system, the pump-down system, and the
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`fluid valve system
`
`[0005]
`
`The present disclosure also introduces an apparatus including a treatment fluid
`
`system, a pump-down system, a fluid valve system, and a controller comprising a processor
`
`and a memory storing a computer program code. The treatment fluid system is operable to
`
`perform well treatment operations by pumping a treatment fluid into a wellbore extending
`
`into a subterranean formation from a surface of an oil and gas wellsite. The pump-down
`
`system is operable to perform pump-down operations by pumping a pump-down fluid into
`
`the well bore to convey a perforating tool within the well bore. The fluid valve system is
`
`operable to fluidly connect the treatment fluid system with the well bore during the well
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`treatment operations and the pump-down system with the well bore during the pump-down
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`operations. The controller is communicatively connected with the treatment fluid system, the
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`pump-down system, and the fluid valve system The controller is operable to, after the well
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`treatment fluid is pumped into the wellbore, operate the fluid valve system to fluidly
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`disconnect the treatment fluid system from the wellbore, operate the fluid valve system to
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`fluidly connect the pump-down system with the well bore, and perform the pump-down
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`operations by operating the pump-down system to pump the pump-down fluid into the
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`well bore to convey the perforating tool within the well bore. The controller is also operable
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`to, after the pump-down fluid is pumped into the well bore and the perforating tool is retrieved
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`from the well bore, operate the fluid valve system to fluidly disconnect the pump-down
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`system from the wellbore, operate the fluid valve system to fluidly connect the treatment
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`fluid system with the well bore, and perform the well treatment operations by operating the
`
`treatment fluid system to pump the treatment fluid into the wellbore.
`
`[0006]
`
`The present disclosure also introduces an apparatus including a treatment fluid
`
`system, a pump-down system, a fluid valve system, and a controller comprising a processor
`
`and a memory storing a computer program code. The treatment fluid system is operable to
`
`perform well treatment operations by pumping a treatment fluid into a first well bore or a
`
`second well bore extending into a subterranean formation from a surface of an oil and gas
`
`2
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`IWS EXHIBIT 1019
`
`EX_1019_005
`
`

`

`Attorney Docket No. IS19.0l 76-US-PSP
`Customer No. 27452
`wellsite. The pump-down system is operable to perform pump-down operations by pumping
`
`a pump-down fluid into the first well bore or the second well bore to convey a perforating tool
`
`within the first well bore or the second wellbore. The fluid valve system is operable to fluidly
`
`connect and disconnect the treatment fluid system with and from the first well bore or the
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`second well bore and to fluidly connect and disconnect the pump-down system with and from
`
`the first well bore or the second well bore. The controller is communicatively connected with
`
`the treatment fluid system, the pump-down system, and the fluid valve system. The
`
`controller is operable to operate the fluid valve system to simultaneously fluidly disconnect
`
`the pump-down system from the first well bore, fluidly connect the treatment fluid system
`
`with the first well bore to permit pumping of the treatment fluid into the first well bore, fluidly
`
`disconnect the treatment fluid system from the second well bore, and fluidly connect the
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`pump-down system with the second well bore to permit pumping of the pump-down fluid into
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`the second well bore to convey the perforating tool within the second well bore.
`
`[0007]
`
`These and additional aspects of the present disclosure are set forth in the
`
`description that follows, and/or may be learned by a person having ordinary skill in the art by
`
`reading the material herein and/or practicing the principles described herein. At least some
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`aspects of the present disclosure may be achieved via means recited in the attached claims.
`
`Brief Description of the Drawings
`
`[0008]
`
`The present disclosure is understood from the following detailed description when
`
`read with the accompanying figures. It is emphasized that, in accordance with the standard
`
`practice in the industry, various features are not drawn to scale. In fact, the dimensions of the
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`various features may be arbitrarily increased or reduced for clarity of discussion.
`
`[0009]
`
`FIG. 1 is a schematic view of at least a portion of an example implementation of
`
`apparatus according to one or more aspects of the present disclosure.
`
`[0010]
`
`FIG. 2 is a schematic view of at least a portion of an example implementation of
`
`apparatus according to one or more aspects of the present disclosure.
`
`[0011]
`
`FIG. 3 is a schematic view of at least a portion of an example implementation of
`
`apparatus according to one or more aspects of the present disclosure.
`
`[0012]
`
`FIG. 4 is a schematic view of at least a portion of an example implementation of
`
`apparatus according to one or more aspects of the present disclosure.
`
`FIG. 5 is a schematic view of at least a portion of an example implementation of
`
`apparatus according to one or more aspects of the present disclosure.
`
`3
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`IWS EXHIBIT 1019
`
`EX_1019_006
`
`

`

`Attorney Docket No. IS19.0l 76-US-PSP
`Detailed Description
`
`Customer No. 27452
`
`[0014]
`
`It is to be understood that the following disclosure provides many different
`
`embodiments, or examples, for implementing different features of various embodiments.
`
`Specific examples of components and arrangements are described below to simplify the
`
`present disclosure. These are, of course, merely examples and are not intended to be limiting.
`
`In addition, the present disclosure may repeat reference numerals and/or letters in the various
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`examples. This repetition is for simplicity and clarity, and does not in itself dictate a
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`relationship between the various embodiments and/or configurations discussed. Moreover,
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`the formation of a first feature over or on a second feature in the description that follows may
`
`include embodiments in which the first and second features are formed in direct contact, and
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`may also include embodiments in which additional features may be formed interposing the
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`first and second features, such that the first and second features may not be in direct contact.
`
`[0015]
`
`FIG. 1 is a schematic view of at least a portion of an example implementation of
`
`an apparatus and/or system according to one or more aspects of the present disclosure. The
`
`figure shows a wellsite 104, multiple wellbores 102 each extending from the terrain surface
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`of the wellsite 104, a partial sectional view of a subterranean formation 106 penetrated by the
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`well bores 102, and a wellsite system 100 comprising various pieces of wellsite equipment or
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`components located at the wellsite 104. FIG. 1 represents an example environment in which
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`one or more aspects of the present disclosure described below may be implemented.
`
`[0016]
`
`The wellsite system 100 may facilitate recovery of oil, gas, and/or other materials
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`that are trapped in the subterranean formation 106. Each wellbore 102 may comprise a
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`casing 108 secured by cement (not shown).
`
`[0017]
`
`The wellsite system 100 may be operable to transfer various materials and
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`additives from corresponding sources to a destination location for blending or mixing and
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`subsequent injection into one or more of the well bores 102 during fracturing and other
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`stimulation operations. Such operations may be partially or fully automated.
`
`[0018]
`
`The wellsite system 100 may comprise a mixing unit 108 (referred to hereinafter
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`as a "mixer") fluidly connected with one or more tanks 110 and a container 112. The
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`container 112 may contain a first material and the tanks 110 may contain a liquid. The first
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`material may be or comprise a hydratable material or gelling agent, such as cellulose, clay,
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`galactomannan, guar, polymers, synthetic polymers, and/or polysaccharides, among other
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`examples. The liquid may be or comprise an aqueous fluid, such as water or an aqueous
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`solution comprising water, among other examples. The mixer 108 may be operable to
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`receive the first material and the liquid, via two or more conduits or other material transfer
`
`4
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`IWS EXHIBIT 1019
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`EX_1019_007
`
`

`

`Customer No. 27452
`Attorney Docket No. 1S19.0176-US-PSP
`means (hereafter simply "conduits") 114, 116, and mix or otherwise combine the first
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`material and the liquid to form a base fluid, which may be or comprise that which is known in
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`the art as a gel. The mixer 108 may then discharge the base fluid via one or more conduits
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`118.
`
`[0019]
`
`The wellsite system 100 may further comprise a mixer 124 fluidly connected with
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`the mixer 108 and a container 126. The container 126 may contain a second material that
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`may be appreciably different than the first material. For example, the second material may be
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`or comprise a proppant material, such as quartz, sand, sand-like particles, silica, and/or
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`propping agents, among other examples. The mixer 124 may be operable to receive the base
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`fluid from the mixer 108 via the one or more conduits 118, and the second material from the
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`container 126 via one or more conduits 128, and mix or otherwise combine the base fluid and
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`the second material to form a mixed fluid. The mixed fluid may be or comprise that which is
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`known in the art as a fracturing fluid. The mixer 124 may then discharge the mixed fluid via
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`one or more conduits 130.
`
`[0020]
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`The mixed fluid may be communicated from the mixer 124 to a common manifold
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`136 via the one or more conduits 130. The common manifold 136 may comprise a low(cid:173)
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`pressure distribution manifold 138, a high-pressure collection and discharge manifold 140, as
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`well as various valves and diverters, such as may be collectively operable to direct the flow
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`of the mixed fluid in a predetermined manner. The common manifold 136 may receive the
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`mixed fluid from the one or more conduits 130 and distribute the mixed fluid to a fleet of
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`pump units 150 via the low-pressure distribution manifold 138. The common manifold 136
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`may be known in the art as a missile or a missile trailer. Although the fleet is shown
`
`comprising four pump units 150, the fleet may comprise other quantities of pump units 150
`
`within the scope of the present disclosure.
`
`[0021]
`
`Each pump unit 150 may comprise a pump 152, a prime mover 154, and perhaps a
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`heat exchanger 156. Each pump unit 150 may receive the mixed fluid from a corresponding
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`outlet of the low-pressure distribution manifold 138 of the common manifold 136, via one or
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`more conduits 142, and discharge the mixed fluid under pressure into a corresponding inlet of
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`the high-pressure collection and discharge manifold 140 via one or more conduits 144. The
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`mixed fluid may then be discharged from the high-pressure collection and discharge manifold
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`140 via one or more conduits 146.
`
`[0022]
`
`The tanks 110, the containers 112, 126, the mixers 108, 124, the pump units 150,
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`the manifold 136, and the conduits 114, 116, 118, 128, 130, 142, 144, 146 may collectively
`
`form a treatment (e.g., stimulation) fluid system. As described above, the treatment fluid
`
`5
`
`IWS EXHIBIT 1019
`
`EX_1019_008
`
`

`

`Attorney Docket No. 1S19.0176-US-PSP
`Customer No. 27452
`system of the wellsite system 100 may be operable to transfer additives and produce a
`
`fracturing fluid that may be pressurized and injected into a selected wellbore 102 during
`
`hydraulic fracturing operations. However, it is to be understood that the treatment fluid
`
`system may also or instead be operable to transfer other additives and mix other treatment
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`fluids that may be pressurized and injected into the selected wellbore 102 during other well
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`and/or reservoir treatment operations, such as acidizing operations, chemical injection
`
`operations, and other stimulation operations, among other examples. Accordingly, unless
`
`described otherwise, the one or more mixed fluids being produced and pressurized by the
`
`treatment fluid system for injection into a selected well bore 102 may be referred to
`
`hereinafter simply as "a treatment fluid."
`
`[0023]
`
`The treatment fluid may be received by a frac manifold 170, which may
`
`selectively distribute the treatment fluid between the wellbores 102 via a plurality of
`
`corresponding fluid conduits 172 extending between the frac manifold 170 and each wellbore
`
`102. The frac manifold 170 may comprise a plurality of remotely operated fluid flow control
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`valves 173 (e.g., frac valves, shut-off valves), each remotely operable to fluidly connect (and
`
`disconnect) the fluid conduit 146 with a selected one or more of the fluid conduits 172 and,
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`thus, facilitate injection of the treatment fluid into a selected one or more of the well bores
`
`102. The frac manifold 170 may be known in the art as a zipper manifold.
`
`[0024]
`
`Each wellbore 102 may be capped by a plurality (e.g., a stack) of fluid flow
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`control devices 174, 176, which may comprise or form a Christmas tree (e.g., a frac tree)
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`comprising fluid flow control valves (e.g., master valves, wing valves, swab valves, etc.),
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`spools, flow crosses (e.g., goat heads, frac heads, etc.), and fittings individually and/or
`
`collectively operable to direct and control (e.g., permit and prevent) flow of the treatment
`
`fluid into the well bore 102 and to direct and control flow of formation fluids out of the
`
`well bore 102. The fluid flow control valves of the fluid flow control device 174, 176 may be
`
`operable to close selected tubulars or pipes, such as the casing 108 or production tubing
`
`extending within the wellbore 102, to selectively facilitate fluid access to the well bore 102.
`
`The fluid flow control devices 174, 176 may also comprise or form a blow-out preventer
`
`(BOP) stack selectively operable to prevent flow of the formation fluids out of the well bore
`
`102. The fluid flow control devices 17 4, 176 may be directly or indirectly mounted on top of
`
`a wellhead 178 (e.g., tubing head adapter) terminating the wellbore 102 at the surface of the
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`wellsite 104. Each fluid flow control valve 173 of the frac manifold 170 may be fluidly
`
`connected with a corresponding fluid flow control device 174 via one or more fluid conduits
`
`172, to facilitate selective fluid connection between the common manifold 136 and one or
`
`6
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`IWS EXHIBIT 1019
`
`EX_1019_009
`
`

`

`Attorney Docket No. 1S19.0176-US-PSP
`Customer No. 27452
`more of the well bores 102. Thus, the fluid flow control valves 173 of the frac manifold 170
`
`and the fluid flow control valves of the fluid flow control devices 174, 176 may collectively
`
`form a fluid flow control valve system operable to fluidly connect (and disconnect) one of the
`
`treatment fluid system and a pump-down system (described below) with a selected one or
`
`more of the well bores 102.
`
`[0025]
`
`A downhole intervention and/or sensor assembly, referred to herein as a tool
`
`string 180, may be conveyed within a selected one of the wellbores 102 via a conveyance line
`
`182 operably coupled with one or more pieces of equipment at the wellsite 104. The tool
`
`string 180 may comprise a perforating tool operable to perforate the casing 108 and a portion
`
`of the formation 106 surrounding the well bore 102 during perforating operations. The
`
`conveyance line 182 may be or comprise a cable, a wireline, a slickline, a multiline, an e-line,
`
`coiled tubing, and/or other conveyance means.
`
`[0026]
`
`The conveyance line 182 may be operably connected with a conveyance device
`
`184 (e.g., a wireline or coiled tubing conveyance unit) operable to apply an adjustable tension
`
`to the tool string 180 via the conveyance line 182 to convey the tool string 180 along the
`
`well bore 102. The conveyance device 184 may be or comprise a winch conveyance system
`
`comprising a reel or drum 186 storing thereon a wound length of the conveyance line 182.
`
`The drum 186 may be rotated by a rotary actuator (e.g., an electric motor, a hydraulic motor,
`
`etc.) (not shown) to selectively unwind and wind the conveyance line 182 to apply an
`
`adjustable tensile force to the tool string 180 to selectively convey the tool string 180 into and
`
`out of the well bore 102. The conveyance line 182 may be directed, guided, and/or injected
`
`(e.g., pushed downhole) into the wellbore 102 by an injection device 188 (e.g., a sheave, a
`
`pulley, a coiled tubing injector), one or more of which may be supported above the well bore
`
`102 via a mast, a derrick, a crane, and/or another support structure (not shown). The
`
`conveyance line 182 may comprise and/or be operable in conjunction with means for
`
`communication between the tool string 180, the conveyance device 184, and/or one or more
`
`other portions of the surface equipment, including a tool string control system
`
`[0027]
`
`The tool string 180 may be deployed into or retrieved from the well bore 102 via
`
`the conveyance device 184 through the fluid flow control devices 174, 176, the wellhead 178,
`
`and/or a sealing and alignment assembly 189 mounted on the fluid flow control devices 174,
`
`176 and operable to seal the conveyance line 182 during deployment, conveyance,
`
`intervention, and other wellsite operations performed via the tool string 180. The injection
`
`device 188 may, thus, guide the conveyance line 182 between the conveyance device 184 and
`
`the sealing and alignment assembly 189. The sealing and alignment assembly 189 may
`
`7
`
`IWS EXHIBIT 1019
`
`EX_1019_010
`
`

`

`Customer No. 27452
`Attorney Docket No. 1S19.0176-US-PSP
`comprise a lock chamber (e.g., a lubricator, an airlock, a riser, etc.) mounted on the fluid flow
`
`control devices 17 4, 176, and a stuffing box operable to seal around the conveyance line 182
`
`at the top of the lock chamber. The stuffing box may be operable to seal around an outer
`
`surface of the conveyance line 182, such as via annular packings applied around the surface
`
`of the conveyance line 182 and/or by injecting a fluid between the outer surfaces of the
`
`conveyance line 182 and an inner wall of the stuffing box.
`
`[0028]
`
`The sealing and alignment assembly 189 and the injection device 188 may be
`
`disconnected from above a well bore 102 that was perforated and is now ready for stimulation
`
`(e.g., fracturing operations), and may be installed or connected above a wellbore 102 that is
`
`to be perforated in preparation for stimulation. The sealing and alignment assembly 189 and
`
`the injection device 188 may be moved from wellbore 102 to wellbore 102 and supported
`
`above a wellbore 102 by a crane or other lifting equipment. The conveyance device 184, the
`
`sealing and alignment assembly 189, the injection device 188, the tool string 180, and the
`
`conveyance line 182 may collectively form at least a portion of a perforating system operable
`
`to convey the tool string 180 (including the perforating tool) within and out of a well bore 102
`
`and to perforate the well bore 102.
`
`[0029]
`
`The wellsite system 100 may further comprise a pump-down system operable to
`
`inject a fluid (e.g., water) into a selected one of the wellbores 102 to perform pump-down
`
`operations to convey the tool string 180 to an intended depth along the well bore 102. The
`
`pump-down operations may be utilized to move the tool string 180 along the wellbore 102 to
`
`facilitate wellbore plugging and perforating ("plug and perf') operations. For example, the
`
`tool string 180 may be conveyed along the wellbore 102 to fluidly isolate an upper formation
`
`zone that has not yet been perforated from a lower formation zone that has already been
`
`perforated, and then perforate the upper formation zone. The pumping system may comprise
`
`a pump unit 190 operable to inject the fluid from a fluid container 194 into the selected one of
`
`the wellbores 102 containing the tool string 180 via a corresponding fluid flow control device
`
`176 (or wellhead 178). Each pump unit 190 may comprise a fluid pump 192, a prime mover
`
`193 for actuating the fluid pump 192, and perhaps a heat exchanger 195. The fluid pump 192
`