BAKER HUGHES INCORPORATED AND
`BAKER HUGHES OILFIELD
`OPERATIONS, INC.
`Exhibit 1009
`BAKER HUGHES INCORPORATED AND
`BAKER HUGHES OILFIELD
`OPERATIONS, INC. v. PACKERS PLUS
`ENERGY SERVICES, INC.
`IPR2016-00596
`
`Page 1 of 3
`
`

`
`A PRIMER OF
`
`OILWELL DRILLING
`
`A Basic Text of Oil and Gas Drilling
`
`Fifth Edition
`
`(Revised)
`
`by Ron Baker
`
`
`
`published by
`
`PETROLEUM EXTENSION SERVICE
`
`Division of Continuing Education
`
`The University of Texas at Austin
`Austin, Texas
`
`in cooperation with
`
`INTERNATIONAL ASSOCIATION
`
`OF DRILLING CONTRACTORS
`
`Houston, Texas
`
`1996
`
`Page 1 of 3
`Page 1 of 3
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`

`
`I
`
`COMPLETING THE WELL
`RUNNING TUBING AND INSTALLING
`THE CHRISTMAS TREE
`After the well is perforated, oil and gas can flowinto the casing
`or liner. Usually, however, the operator does not produce the
`well by allowing hydrocarbons to flow up the casing or liner.
`Instead, the completion rig crew places small—diameter pipe
`called tubinginside the cased well. In fact, the operator some-
`times runs tubing into the well before perforating it. In such
`cases, the perforating gun is lowered through the tubing to the
`required depth.
`Tubing that meets API specifications has an outside diameter
`that ranges from 1.050 inches (26.7 millimetres) to 41/2 inches
`(114.3 millimetres). Seven sizes in between the two extremes
`are also available. Manufacturers provide joints of tubing in
`two range lengths: range 1 tubingjoints are 20 to 24 feet (6.1 to
`7.3 metres) long; range 2 tubing joints are 28 to 32 feet (8.5 to
`9.8 metres) long. As it does with casing, the crew commonly
`uses couplings to join tubing, although an integral-joint tub-
`ing is available that allows the crew to make up joints without
`using couplings.
`Manufacturers also supply coiled tubing. Coiled tubing is a
`continuous length——it does not have joints—offlexible steel
`pipe that comes rolled on a large reel. Operators have com-
`pleted wells over 20,000 feet (6,000 metres) deep with coiled
`tubing. Special equipment placed at the top ofthe well allows
`crew members to insert, or inject, the tubing into the well as
`they unwind it from the reel (fig. 167). The main advantage of
`coiled tubing is that crew members do not have to connect
`
`147
`
`I
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`Page 2 of 3
`Page 2 of 3
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`

`
`148
`
`A PRIMER OF OILWELL DRILLING
`
`Whether using jointed or coiled tubing, the operator usually
`produces a well through a tubing string rather than through
`the casing for several reasons. For one thing, the crew does not
`cement a tubing string in the well. As a result, when a joint of
`tubing fails, as it almost inevitablywill over the life ofa well, the
`operator can easily replace the failed joint or joints or, in the
`case of coiled tubing, remove and repair or replace the failed
`area. Since casing is cemented, it is very difficult to replace.
`For another thing, tubing allows the operator to control the
`well’s production by placing special tools and devices in or on
`the tubing string. These devices allow the operator to produce
`the well efficiently. In some cases, the operator can produce
`the well only by utilizing a tubing string. Casing does not
`provide a place to install any tools or devices that may be
`required for production. In addition, the operator installs
`safety valves in the tubing string. These valves automatically
`stop the flow of fluids from the well if damage occurs at the
`surface.
`
`Finally, tubing protects the casing from the corrosive and
`erosive effects of produced fluids. Over the life of a well,
`
`reservoir fluids tend to corrode metals with which they are in
`contact. By producing fluids through the tubing, which the
`operator can easily replace, the casing, which is not so easy to
`repair or replace, is preserved.
`Crew members usually run tubing into the well with a sealing
`
`device called a packer. They install the packer on the tubing string
`
`and place it at a depth slightly above the casing perforations. The
`
`end of the tubing is left open or is perforated and extends to a
`
`point opposite the perforations in the casing. The packer
`expands and grips the wall of the production casing or liner.
`When expanded, the packer seals the annular space between
`
`the tubing and the casing above the perforations. The pro-
`duced fluids flow through the perforations and into the tubing
`
`string. The packer prevents them from entering the annular
`space, where they could eventually corrode the casing.
`
`Page 3 of 3
`Page 3 of 3