U.S. patent application number 14/426492 was filed with the patent office on 2017-08-31 for dual service compressor system for conditioning hydrocarbon gas.
This patent application is currently assigned to GE Oil & Gas, Inc.. The applicant listed for this patent is GE Oil & Gas, Inc.. Invention is credited to Rajesh ATHIRATHNAM, Manik KAPOOR, Mohsin KHAN.
Application Number | 20170248130 14/426492 |
Document ID | / |
Family ID | 55653472 |
Filed Date | 2017-08-31 |
United States Patent
Application |
20170248130 |
Kind Code |
A1 |
ATHIRATHNAM; Rajesh ; et
al. |
August 31, 2017 |
DUAL SERVICE COMPRESSOR SYSTEM FOR CONDITIONING HYDROCARBON GAS
Abstract
A system for compressing gas from a wellbore that uses a single
reciprocating compressor unit to boost pressure of the gas to an
intermediate stage, and from the intermediate stage to a final
stage. The final stage is at a destination pressure for
distribution. Between the intermediate and final stages the gas is
treated to remove water and higher molecular weight hydrocarbons so
that the gas pressurized to the final stage is compressed natural
gas. The reciprocating compressor is made up of a series of throw
assemblies that are all driven by a single shaft. Each throw
assembly includes a cylinder with a piston that reciprocates within
the cylinder to compress and pressurize the fluid therein. The
reciprocating compressor can be a non-lube design thereby
eliminating lube oil contamination of downstream compressed natural
gas or higher molecular weight hydrocarbons.
Inventors: |
ATHIRATHNAM; Rajesh;
(Houston, TX) ; KAPOOR; Manik; (Houston, TX)
; KHAN; Mohsin; (Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
GE Oil & Gas, Inc. |
Houston |
TX |
US |
|
|
Assignee: |
GE Oil & Gas, Inc.
Houston
TX
|
Family ID: |
55653472 |
Appl. No.: |
14/426492 |
Filed: |
October 7, 2014 |
PCT Filed: |
October 7, 2014 |
PCT NO: |
PCT/US14/59395 |
371 Date: |
March 6, 2015 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
F04B 35/002 20130101;
F04B 39/0094 20130101; F04B 27/02 20130101; F04B 37/18 20130101;
F04B 39/16 20130101; E21B 43/34 20130101 |
International
Class: |
F04B 37/18 20060101
F04B037/18; F04B 39/00 20060101 F04B039/00; F04B 27/02 20060101
F04B027/02; F04B 39/16 20060101 F04B039/16; E21B 43/34 20060101
E21B043/34; F04B 35/00 20060101 F04B035/00 |
Claims
1. A method of producing compressed natural gas, the method
comprising: providing a reciprocating compressor having a booster
cylinder and a compressed natural gas (CNG) cylinder; directing an
amount of gas from a wellbore to the compressor; compressing the
amount of gas in the booster cylinder to an intermediate stage
pressure to define an amount of intermediate stage gas; directing
the intermediate stage gas to the CNG cylinder; and compressing the
intermediate stage gas in the CNG cylinder to a destination
pressure to form compressed natural gas.
2. The method of claim 1, further comprising treating the
intermediate stage gas prior to directing the intermediate stage
gas to the second one of the cylinders.
3. The method of claim 2, wherein treating the intermediate stage
gas comprises separating higher molecular weight hydrocarbons from
the intermediate stage gas.
4. The method of claim 2, wherein treating the intermediate stage
gas comprises removing moisture from the intermediate stage
gas.
5. The method of claim 4, wherein removing moisture from the
intermediate stage gas comprises adding a hygroscopic agent to the
intermediate stage gas.
6. The method of claim 1, wherein the booster cylinder comprises a
first booster cylinder and a second booster cylinder, and wherein a
discharge of the first booster cylinder connects to a suction in
the second booster cylinder.
7. The method of claim 1, wherein the CNG cylinder comprises a
first CNG cylinder and a second CNG cylinder, and wherein a
discharge of the first CNG cylinder connects to a suction in the
second CNG cylinder.
8. The method of claim 1, wherein the reciprocating compressor
comprises a body, a shaft extending axially through the body,
pistons in the booster and CNG cylinders coupled to the shaft, and
a motor connected to the shaft, the method further comprising
activating the motor to rotate the shaft and to reciprocate the
pistons in the cylinders.
9. The method of claim 8, wherein the reciprocating compressor
further comprises a control panel on the body, the method further
comprising manipulating the control panel to operate the motor.
10. The method of claim 1 further comprising removing moisture from
the gas from the wellbore before directing the gas from the
wellbore to the compressor.
11. The method of claim 1, wherein the reciprocating compressor is
a non-lube design.
12. The method of claim 11, wherein the motor comprises an internal
combustion engine powered by gas from the wellbore.
13. A method of producing compressed natural gas, the method
comprising: providing a reciprocating compressor having a body, a
shaft in the body, a series of cylinders that extend radially
outward from the body, and pistons in the cylinders; supplying
fluid from a wellbore to a one of the cylinders that is designated
as a booster cylinder; creating intermediate stage fluid by
pressurizing the fluid in the booster cylinder; removing moisture
from the intermediate stage fluid to form intermediate stage gas;
and forming an amount of compressed natural gas by pressurizing the
intermediate stage gas in another one of the cylinders.
14. The method of claim 13, further comprising removing higher
molecular weight hydrocarbons from the intermediate stage
fluid.
15. The method of claim 13, wherein the series of cylinders
comprises a multiplicity of booster cylinders.
16. The method of claim 13, wherein the another one of the
cylinders comprises a compression cylinder, and wherein the series
of cylinders comprises a multiplicity of compression cylinders.
17. A compression system for generating compressed natural gas
comprising: a body; cylinders mounted on the body and pistons in
the cylinders that comprise a booster compressor and a compressed
natural gas compressor; a feed line containing fluid from a
wellbore and having an end connected to a suction side of the
booster compressor; a suction side on the compressed natural gas
compressor that is in fluid communication with a discharge side on
the booster compressor via an intermediate circuit; and a discharge
line containing compressed natural gas and connected to a discharge
side of the compressed natural gas compressor.
18. The compression system of claim 17, further comprising a
dehumidification system disposed in the intermediate circuit.
19. The compression system of claim 17, further comprising a tank
disposed in the intermediate circuit for removing higher molecular
weight hydrocarbons.
20. The compression system of claim 17, further comprising a
crankshaft coupled with each of the pistons, and a motor coupled
with the crankshaft.
21. The compression system of claim 20, further comprising a
control system mounted on the body and in signal communication with
the motor.
Description
BACKGROUND OF THE INVENTION
[0001] Field of the Invention
[0002] The present disclosure relates in general to a system and
method for compressing gas from a hydrocarbon producing well, where
the gas is compressed to an intermediate pressure and to a final
discharge pressure within a single unit.
[0003] Description of Prior Art
[0004] Systems for forming compressed natural gas (CNG) typically
include a booster compressor that compresses the feed gas to an
intermediate stage pressure. While at the intermediate stage
pressure, the gas is treated to remove natural gas liquids, which
typically include constituents having two or more carbon atoms. The
remaining gas, the majority of which generally is made up of
methane, is then compressed with a second compressor commonly
referred to as a CNG compressor. The booster compressor and CNG
compressor can often each have a weight in excess of 75,000 pounds
and occupy a significant amount of space. CNG compressors use
electric motors; when disposed in remote locations the motors
require onsite generators for their power.
SUMMARY OF THE INVENTION
[0005] Disclosed herein is an example of a method of producing
natural gas that includes providing a reciprocating compressor
having a booster cylinder and a compressed natural gas (CNG)
cylinder, directing an amount of gas from a wellbore to the
compressor, compressing the amount of gas in the booster cylinder
to an intermediate stage pressure to define an amount of
intermediate stage gas, directing the intermediate stage gas to the
CNG cylinder, and compressing the intermediate stage gas in the CNG
cylinder to a destination pressure to form compressed natural gas.
The method may further include treating the intermediate stage gas
prior to directing the intermediate stage gas to the second one of
the cylinders. In this example, treating the intermediate stage gas
involves separating higher molecular weight hydrocarbons from the
intermediate stage gas. Further in this example, treating the
intermediate stage gas removes moisture from the intermediate stage
gas. Removing moisture from the intermediate stage gas can take
place by adding a hygroscopic agent to the intermediate stage gas.
In an embodiment, the booster cylinder is made up of a first
booster cylinder and a second booster cylinder, and wherein a
discharge of the first booster cylinder connects to a suction in
the second booster cylinder. In an example, the CNG cylinder is a
first CNG cylinder and a second CNG cylinder, and wherein a
discharge of the first CNG cylinder connects to a suction in the
second CNG cylinder. The reciprocating compressor may include a
body, a shaft extending axially through the body, pistons in the
booster and CNG cylinders coupled to the shaft, and a motor/engine
connected to the shaft, the method further including activating the
motor/engine to rotate the shaft and to reciprocate the pistons in
the cylinders. The reciprocating compressor may further have a
control panel on the body, the method further involving
manipulating the control panel to operate the motor/engine.
Moisture may be removed from the gas from the wellbore before
directing the gas from the wellbore to the compressor.
[0006] Another method of producing compressed natural gas disclosed
herein includes providing a reciprocating compressor having a body,
a shaft in the body, a series of cylinders that extend radially
outward from the body, and pistons in the cylinders, supplying
fluid from a wellbore to a one of the cylinders that is designated
as a booster cylinder, creating intermediate stage fluid by
pressurizing the fluid in the booster cylinder, removing moisture
from the intermediate stage fluid to form intermediate stage gas,
and forming an amount of compressed natural gas by pressurizing the
intermediate stage gas in another one of the cylinders. Higher
molecular weight hydrocarbons can be removed from the intermediate
stage fluid. The series of cylinders can be a multiplicity of
booster cylinders. Optionally, the another one of the cylinders is
a compression cylinder, and wherein the series of cylinders are a
multiplicity of compression cylinders.
[0007] Also disclosed herein is a compression system for generating
compressed natural gas that has a body, cylinders mounted on the
body and pistons in the cylinders that comprise a booster
compressor and a compressed natural gas compressor, a feed line
containing fluid from a wellbore and having an end connected to a
suction side of the booster compressor, a suction side on the
compressed natural gas compressor that is in fluid communication
with a discharge side on the booster compressor via an intermediate
circuit, and a discharge line containing compressed natural gas and
connected to a discharge side of the compressed natural gas
compressor. The compression system may also have a dehumidification
system disposed in the intermediate circuit. Optionally, a tank can
be disposed in the intermediate circuit for removing higher
molecular weight hydrocarbons. A crankshaft may be included with
the compression system that is coupled with each of the pistons,
and a motor/engine can be included that is coupled with the
crankshaft. Further included with this example is a control system
mounted on the body and in signal communication with the
motor/engine.
BRIEF DESCRIPTION OF THE DRAWINGS
[0008] Some of the features and benefits of the present invention
having been stated, others will become apparent as the description
proceeds when taken in conjunction with the accompanying drawings,
in which:
[0009] FIG. 1 is a schematic view of an example of a system for
processing fluid from a wellbore.
[0010] FIG. 2 is a schematic example of a dual service compressor
for use with the system of FIG. 1.
[0011] While the invention will be described in connection with the
embodiments, it will be understood that it is not intended to limit
the invention to that embodiment. On the contrary, it is intended
to cover all alternatives, modifications, and equivalents, as may
be included within the spirit and scope of the invention as defined
by the appended claims.
DETAILED DESCRIPTION OF THE INVENTION
[0012] The method and system of the present disclosure will now be
described more fully hereinafter with reference to the accompanying
drawings in which embodiments are shown. The method and system of
the present disclosure may be in many different forms and should
not be construed as limited to the illustrated embodiments set
forth herein; rather, these embodiments are provided so that this
disclosure will be thorough and complete, and will fully convey its
scope to those skilled in the art. Like numbers refer to like
elements throughout. In an embodiment, usage of the term "about"
includes +/-5% of the cited magnitude. In an embodiment, usage of
the term "substantially" includes +/-5% of the cited magnitude.
[0013] It is to be further understood that the scope of the present
disclosure is not limited to the exact details of construction,
operation, exact materials, or embodiments shown and described, as
modifications and equivalents will be apparent to one skilled in
the art. In the drawings and specification, there have been
disclosed illustrative embodiments and, although specific terms are
employed, they are used in a generic and descriptive sense only and
not for the purpose of limitation.
[0014] An example of a compressed natural gas (CNG) system 10 is
schematically illustrated in FIG. 1. The CNG system 10 is
downstream of a wellhead assembly 12 shown mounted over a wellbore
14 that intersects a formation 16. Hydrocarbons, both liquid and
gas, from the wellbore 14 are produced through the wellhead
assembly 12 and transmitted from wellhead assembly 12 via a
connected production line 18. Production line 18 terminates in a
header 20. The header 20 may optionally be the destination for
other production lines 22, 24, 26 that also transmit production
fluid from other wellhead assemblies (not shown). A feed line 28
provides a communication means between the header 20 and CNG system
10. The end of feed line 28 distal from header 20 terminates in a
knockout drum 30 and which optionally provides a way of separating
water and other liquids from the feedline 28. A drain line 32
connects to a bottom of knockout drum 30 and directs liquids
separated out from the fluid flow in feed line 28. The gas portion
of the fluid in feed line 28 directed into knockout drum 30 exits
knockout drum 30 through an overhead line 34 shown extending from
an upper end of knockout drum 30. The end of overhead line 34
distal from knockout drum 30 connects to a suction line of a
compressor 36. In the example of FIG. 1, compressor 36 includes a
booster compressor 38 and a CNG compressor 40. In this example,
overhead line 34 terminates at a suction end of booster compressor
38 so that the gas in line 34 can be pressurized to an interstage
pressure.
[0015] The interstage gas discharged from booster compressor 38 is
treated in an interstage conditioning system 42. More specifically,
a discharge line 46 provides communication between a discharge side
of booster compressor 38 to a dehydration unit 48. In one
alternative, an injection line 50 for injecting hygroscopic agent
into the intermediate stage gas flow stream is shown connected to
dehydration unit 48. In one example the hygroscopic agent includes
triethylene glycol (TEG), and extracts moisture contained within
the interstage gas. A discharge line 52 is shown connected to
dehydration unit 48, and provides a means for moisture removal from
the intermediate stage gas. Overhead line 54 is shown connected to
an upper end of unit 48 and which is directed to a heat exchanger
56. Within heat exchanger 56, fluid from within overhead line is in
thermal communication with fluid flowing through a bottoms line 58;
where bottoms line 58 connects to a lower end of natural gas liquid
(NGL) tank 60. Downstream of heat exchanger 56, overhead line 54
connects to a heat exchanger 62. Flowing through another side of
heat exchanger 62 is fluid from an overhead line 64, where as shown
overhead line 64 attaches to an upper end of NGL tank 60. An
optional chiller 66 is shown downstream of heat exchanger 62 in
line with overhead line 54. Further in the example of: FIG. 1 is a
control valve 68 illustrated in overhead line 54 and just upstream
of where line 54 intersects with NGL tank 60. Liquid within line 58
is transmitted to offsite 70, and is controlled to offsite 70 via a
valve 72 also shown set within line 58. Valve 72 can be manually or
motor operated.
[0016] Overhead line 64 is shown connected to a suction end of CNG
compressor 40 and where the gas within overhead line 64 is
compressed to a CNG pressure. A discharge line 74 connects to a
discharge side of CNG compressor 40 and provides a conveyance means
for directing the compressed natural gas from CNG compressor 40 to
a tube trailer 76. Optionally, a valve 78 is provided in discharge
line 74 and for regulating flow through discharge line 74; and to
selectively fill tube trailer 76. Alternatively, each booster
compressor 38 may include a first stage 80 and second stage 82. In
this example, discharge from first stage 80 flows through suction
of second stage 82 for additional pressurization. Similarly, CNG
compressor 40 contains a first stage 84 and second stage 86,
wherein gas within first stage 84 is transmitted to a suction side
of second stage 86 for additional compression. Examples exist
wherein the booster compressor 38 and CNG compressor 40 are
reciprocating compressors and wherein each have a number of throws,
wherein some of these throws may be what is commonly referred to as
tandem throws.
[0017] In one example of operation, a multiphase fluid from well 14
flows through lines 18, 20, 28 and is directed to knockout drum 30.
Embodiments exist where the fluid flowing through these lines
contains at least an amount of flare gas, which might commonly be
sent to a flare and combusted onsite. An advantage of the present
disclosure is the ability to economically and efficiently produce
an amount of compressed natural gas that may be captured and
ultimately marketed for sale. Liquid within the fluid in line 28
out flows to a bottom portion of knockout drum 30 and is separated
from gas within the fluid. From within drum 30, the gas is directed
into overhead line 34. Line 34 delivers the gas to the suction of
booster compressor 38, where in one example the gas is pressurized
from an expected pressure between 50 to 100 psig to a pressure of
400 psig, and which forms the interstage gas. Gas, which may
include hydrocarbons, is directed through line 46 into drum 48. For
the purposes of discussion herein, lower molecular weight
hydrocarbons are referred to those having up to two carbon atoms,
wherein higher molecular weight hydrocarbons include those having
three or more carbon atoms. To remove moisture from within the
interstage gas in line 46, hygroscopic agent is directed from
injection line 50 into dehydration unit 48 and allowed to contact
the gas within dehydration unit 48. Alternatively, a molecular
sieve 88 may be provided within dehydration unit 48. Hygroscopic
agent, or sieve 88, can then absorb moisture within the interstage
gas. Sieve 88 may be regenerated after a period of time to remove
the moisture captured within spatial interstices in the sieve 88.
Regeneration can be by pressure swing adsorption or temperature
swing adsorption.
[0018] To remove higher molecular weight hydrocarbons from the
interstage gaseous mixture in line 54, the fluid making up the
mixture is cooled within exchangers 56 and 62 and flashed across
valve 68. Cooling the fluid stream, and then lowering the pressure
across valve 68, is an example of a Joule-Thompson method of
separation and can condense higher molecular weight hydrocarbons
out of solution and into tank 60. The resulting condensate can be
gravity fed from within tank 60 and to offsite 70. An optional
flare 90 is schematically illustrated in communication with fluid
from the wellbore 14 via an end of header 20. Fluid in header 20
can be routed to flare 90 when system 10 is being maintained or
otherwise out of service.
[0019] In alternatives employing the optional chiller 66, the
higher molecular weight hydrocarbons are separated from the fluid
stream by a mechanical refrigeration unit instead of the
Joule-Thompson method of gas conditioning. In examples where the
Joule-Thompson method is employed, the discharge from the booster
compressor 38 can be at about 1,000 psig. In examples using the
mechanical refrigeration method, the discharge from the booster
compressor 38 can be at a pressure of around 400 psig. An advantage
of treating the gas at the interstage pressure is the ability to
remove additional moisture from the gas as well as to optimize the
separation of the higher molecular weight hydrocarbons. As such, a
higher quality of compressed natural gas can be obtained and
delivered via line 74 into the tube trailer 76. Moreover, a higher
quality of NGL can be delivered to offsite 70. In currently known
processes, methanol is sometimes added to the gas mixture to
prevent the formation of hydrates during the gas treatment process.
However, the addition of methanol is not only costly, but also
reduces the quality and marketability of the end products.
[0020] Referring now to FIG. 2 shown is a schematic side sectional
example of the compressor 36, where the compressor 36 includes a
body 90. Throw assemblies 92, 94, 96, 98 are shown coupled to the
body 90 and each along a path generally transverse to an axis of
the body 90. Cylinders 100, 102, 104, 106 are shown respectively in
each of the throw assemblies 92, 94, 96, 98. Shown in each of the
cylinders 100, 102, 104, 106 are pistons 108, 110, 112, 114, which
reciprocate in the cylinders 100, 102, 104, 106 to compress gas
within the cylinders 100, 102, 104, 106. Piston rods 116, 118, 120,
122 respectively connect pistons 108, 110, 112, 114 to a crankshaft
124 shown projecting axially through the body 90. The crankshaft
124 is driven by a motor 126 shown optionally mounted to the body
90. Operating the motor 126 causes rotation of the crankshaft 124,
which in turn reciprocates pistons 108, 110, 112, 114 within their
respective cylinders 100, 102, 104, 106. In one example, the motor
126 includes an internal combustion engine that can be powered by
gasoline, gas from the wellbore 14, another combustible material,
or combinations thereof. In another alternative, the motor 126 can
be electrically powered.
[0021] Further shown in the example of FIG. 2 is that throw
assemblies 92, 94, are included in the booster compressor 38
portion of compressor 36. In this example overhead line 34
terminates in throw assembly 92, so that gas exiting overhead line
34 can be compressed by reciprocation of piston 108 within cylinder
100. Gas being compressed in cylinder 100 by piston 108 is
transmitted to throw assembly 94 via line 128. Gas exiting line 128
into cylinder 102 can be compressed by reciprocating piston 110.
Gas compressed within cylinder 102 exits into discharge line 46,
where it is transmitted to interstage conditioning system 42.
[0022] Throw assemblies 96, 98 are shown in CNG compressor 40
portion of compressor 36. As shown, overhead line 64 terminates at
throw assembly 96 so that interstage gas from interstage
conditioning system 42 is transmitted into cylinder 104.
Reciprocation of piston 112 in cylinder 104 compresses gas exiting
overhead line 64. Gas compressed in the cylinder 104 is transmitted
to throw assembly 98 via line 130 shown having an upstream end
connected to cylinder 104 and a downstream end connected to
cylinder 106. Piston 114 compresses the gas exiting line 130 into
cylinder 106, which is then discharged into discharge line 74. A
control panel 132 for sending controls to the compressor 36, and/or
motor 126 is shown adjacent body 90 and connects to body 90 via bus
134. In and embodiment, bus 134 provides connection for
transmitting signals and/or power to body 90 and motor 126 from
control panel 132. Further shown is a power line 136 connected to
motor 126, which can convey fuel to motor 126 in embodiments when
motor 126 is an internal combustion engine. Alternatively, power
line 136 can provide electricity to motor 126 when motor 126 is
powered by electricity.
[0023] The present invention described herein, therefore, is well
adapted to carry out the objects and attain the ends and advantages
mentioned, as well as others inherent therein. While embodiments of
the invention have been given for purposes of disclosure, numerous
changes exist in the details of procedures for accomplishing the
desired results. In one example the compressor is a non-lube
design, an advantage of which is the reduction of oil and
associated equipment requirements, e.g. day tank, strainer, and/or
heavy weight oil. A non-lube design can prevent oil carry over to
downstream equipment like NGL storage tank, tube trailer, molecular
sieves, etc., which eliminates the need of filtration equipment for
critical processes and alleviates any operational issues such as
contamination, catalyst degradation and the like. Moreover, oil
cost savings that results in direct operating expenditures saving
for end users. An additional advantage is that a non-lube design
eliminates the need for forced feed lubrication system (pumps, PSV,
internal gearing, labor etc.) to all cylinders, and packing. It
also eliminates the auxiliary components/instrumentation such as
tubing, check valves, poppet valves, distribution blocks, no-flow
switch etc. This would in turn reduce the overall compressor price
to customer. The non-lube cylinder design can implement
non-metallic wear resistant materials for internal moving
components and by the use of appropriate clearances to maximize
heat dissipation in the absence of lube oil. These and other
similar modifications will readily suggest themselves to those
skilled in the art, and are intended to be encompassed within the
spirit of the present invention disclosed herein and the scope of
the appended claims.
* * * * *