Recycling gaseous hydrocarbons

Abstract

A method of recycling gaseous hydrocarbons includes flowing a hydrocarbon gas composition from a secondary separator into a compressor unit to form a compressed mixture. The secondary separator includes a crude liquid hydrocarbon input stream from a primary separator. The method includes flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition comprising liquid hydrocarbons. The method includes flowing the liquid hydrocarbons from the cooled composition into the primary separator.

Claims

1. A method of recycling gaseous hydrocarbons, the method comprising: flowing a hydrocarbon gas composition from a secondary separator into a compressor unit to form a compressed mixture, wherein the secondary separator comprises a crude liquid hydrocarbon input stream from a primary separator; flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition comprising liquid hydrocarbons; and flowing the liquid hydrocarbons from the cooled composition into the primary separator, wherein the primary separator comprises a crude hydrocarbon input stream and comprises an output stream comprising the crude liquid hydrocarbon stream that is inputted to the secondary separator.

2. The method of claim 1, wherein the crude hydrocarbon input stream is from an oil well at an on-shore oil recovery or production facility.

3. The method of claim 1, wherein the crude hydrocarbon input stream has a pressure of 10 psi (70 kPa) to 500 psi (3447 kPa).

4. The method of claim 1, wherein the primary separator comprises a two-phase separator or a three-phase separator.

5. The method of claim 1, wherein the hydrocarbon gas composition from the secondary separator is less than 50 mole % methane and is predominantly ethane, propane, and butane.

6. The method of claim 1, wherein the hydrocarbon gas composition from the secondary separator has a pressure of 5 psi (34 kPa) to 80 psi (552 kPa).

7. The method of claim 1, further comprising flowing the hydrocarbon gas composition from the secondary separator to a primary recovery separator, and flowing the hydrocarbon gas composition from the primary recovery separator to the compressor.

8. The method of claim 7, wherein the primary recovery separator comprises a scrubber.

9. The method of claim 1, wherein the compressor comprises an oilless compressor, wherein the oilless compressor comprises a crankcase that is free of oil that contacts material being compressed and is free of oil lubrication that requires regular changings.

10. The method of claim 1, wherein the compressed mixture has a pressure of 100 psi (689 kPa) to 500 psi (3447 kPa) and a temperature of 100° C. to 300° C.

11. The method of claim 1, wherein the cooling unit comprises a heat exchanger, a refrigeration unit, an aftercooler, or a combination thereof.

12. The method of claim 1, wherein the cooling unit comprises an air-cooled heat exchanger.

13. The method of claim 1, wherein the cooled composition has a pressure of 100 psi (689 kPa) to 500 psi (3447 kPa) and a temperature of 0° C. to 80° C.

14. The method of claim 1, further comprising flowing the cooled composition comprising liquid hydrocarbons to a secondary recovery separator before flowing the liquid hydrocarbons into the primary separator.

15. The method of claim 14, wherein the secondary recovery separator comprises a separator column.

16. The method of claim 1, wherein the secondary separator comprises a two-phase separator or a three-phase separator.

17. The method of claim 1, wherein the secondary separator comprises a heater-treater.

18. The method of claim 1, wherein the liquid hydrocarbons flowed into the primary separator comprise a stream having less than 10 ppm oxygen.

19. A method of recycling gaseous hydrocarbons, the method comprising: flowing a hydrocarbon gas composition from a secondary separator into a compressor unit to form a compressed mixture, wherein the secondary separator comprises a crude hydrocarbon input stream; flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition comprising liquid hydrocarbons; and flowing the liquid hydrocarbons from the cooled composition into a primary separator, wherein the primary separator comprises an output stream comprising a liquid hydrocarbon stream that is inputted to the secondary separator.

20. An apparatus for recycling gaseous hydrocarbons, the apparatus comprising: a compressor that accepts a hydrocarbon gas composition from a secondary separator, wherein the secondary separator accepts a crude liquid hydrocarbon input stream from a primary separator, wherein the primary separator comprises a crude hydrocarbon input stream and comprises an output stream that comprises the crude liquid hydrocarbon stream that is inputted to the secondary separator; a cooling unit that accepts the compressed mixture from the compressor and that forms a cooled composition comprising liquid hydrocarbons; and a flowline from the cooling unit for flowing the liquid hydrocarbons to the primary separator.

Description

BRIEF DESCRIPTION OF THE FIGURES

(1) The drawings illustrate generally, by way of example, but not by way of limitation, various aspects of the present invention.

(2) FIG. 1 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects.

(3) FIG. 2 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects.

(4) FIG. 3 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects.

(5) FIG. 4 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects.

DETAILED DESCRIPTION OF THE INVENTION

(6) Reference will now be made in detail to certain aspects of the disclosed subject matter. While the disclosed subject matter will be described in conjunction with the enumerated claims, it will be understood that the exemplified subject matter is not intended to limit the claims to the disclosed subject matter.

(7) Throughout this document, values expressed in a range format should be interpreted in a flexible manner to include not only the numerical values explicitly recited as the limits of the range, but also to include all the individual numerical values or sub-ranges encompassed within that range as if each numerical value and sub-range is explicitly recited. For example, a range of “about 0.1% to about 5%” or “about 0.1% to 5%” should be interpreted to include not just about 0.1% to about 5%, but also the individual values (e.g., 1%, 2%, 3%, and 4%) and the sub-ranges (e.g., 0.1% to 0.5%, 1.1% to 2.2%, 3.3% to 4.4%) within the indicated range. The statement “about X to Y” has the same meaning as “about X to about Y,” unless indicated otherwise. Likewise, the statement “about X, Y, or about Z” has the same meaning as “about X, about Y, or about Z,” unless indicated otherwise.

(8) In this document, the terms “a,” “an,” or “the” are used to include one or more than one unless the context clearly dictates otherwise. The term “or” is used to refer to a nonexclusive “or” unless otherwise indicated. The statement “at least one of A and B” or “at least one of A or B” has the same meaning as “A, B, or A and B.” In addition, it is to be understood that the phraseology or terminology employed herein, and not otherwise defined, is for the purpose of description only and not of limitation. Any use of section headings is intended to aid reading of the document and is not to be interpreted as limiting; information that is relevant to a section heading may occur within or outside of that particular section.

(9) In the methods described herein, the acts can be carried out in any order without departing from the principles of the invention, except when a temporal or operational sequence is explicitly recited. Furthermore, specified acts can be carried out concurrently unless explicit claim language recites that they be carried out separately. For example, a claimed act of doing X and a claimed act of doing Y can be conducted simultaneously within a single operation, and the resulting process will fall within the literal scope of the claimed process.

(10) The term “about” as used herein can allow for a degree of variability in a value or range, for example, within 10%, within 5%, or within 1% of a stated value or of a stated limit of a range, and includes the exact stated value or range. The term “substantially” as used herein refers to a majority of, or mostly, as in at least about 50%, 60%, 70%, 80%, 90%, 95%, 96%, 97%, 98%, 99%, 99.5%, 99.9%, 99.99%, or at least about 99.999% or more, or 100%. The term “substantially free of” as used herein can mean having none or having a trivial amount of, such that the amount of material present does not affect the material properties of the composition including the material, such that about 0 wt % to about 5 wt % of the composition is the material, or about 0 wt % to about 1 wt %, or about 5 wt % or less, or less than or equal to about 4.5 wt %, 4, 3.5, 3, 2.5, 2, 1.5, 1, 0.9, 0.8, 0.7, 0.6, 0.5, 0.4, 0.3, 0.2, 0.1, 0.01, or about 0.001 wt % or less, or about 0 wt %.

(11) Method of Recycling Gaseous Hydrocarbons.

(12) Various aspects of the present invention provide a method of recycling gaseous hydrocarbons. The method can include flowing a hydrocarbon gas composition from a secondary separator to form a compressed mixture. The secondary separator can accept a crude liquid hydrocarbon input stream from a primary separator. The primary separator can include a crude hydrocarbon input stream and can include an output stream including the crude liquid hydrocarbon stream that is inputted to the secondary separator. The method can include flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition including liquid hydrocarbons. The method can also include flowing the liquid hydrocarbons to the primary separator to recycle and recover the liquid hydrocarbons.

(13) The crude hydrocarbon input stream can be any suitable hydrocarbon input stream. For example, the crude hydrocarbon input stream can be from an oil well. The oil well can be at an on-shore oil recovery or production facility or an off-shore oil recovery or production facility. The crude hydrocarbon input stream can have any suitable pressure, such as a pressure of 10 psi (70 kPa) to 500 psi (3447 kPa), or 50 psi (345 kPa) to 100 psi (689 kPa).

(14) The primary separator can be any suitable separator that performs separation on the crude hydrocarbon input stream. The primary separator accepts the crude hydrocarbon input stream and outputs a crude hydrocarbon liquid stream and a crude hydrocarbon gaseous stream (e.g., sales and/or flare gas). The primary separator can also optionally output a water stream. The primary separator can include a two-phase separator (e.g., having liquid and gaseous outputs) or a three-phase separator (e.g., having a water output, a liquid hydrocarbon output, and a gaseous output). The primary separator can be heated (e.g., a heater-treater). The primary separator can be unheated (e.g., free-water-knockout (FWKO)). The primary separator can include a separator column. The primary separator can include a level sensor to detect a height of liquid such as water and/or hydrocarbons. The primary separator can be operated at a pressure greater than 50 psi, such as 50-500 psi.

(15) The hydrocarbon gas composition from the secondary separator is rich gas that is rich in ethane, propane, and butane, and has less than 50 mole % methane (e.g., 1 to 50 mole % methane). The hydrocarbon gas composition can have any suitable oxygen concentration, such as an oxygen concentration of 0 mole % to 20 mole % oxygen, or 1 mole % to 15 mole %, or 3 mole % to 6 mole %, or less than or equal to 20 mole % and greater than or equal to 0 mole %, 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, or 19 mole % oxygen. In various aspects, the hydrocarbon gas composition is less than 10 mole % methane, up to 90 mole % ethane, propane, butane, and pentane, and up to 10 mole % of hydrocarbons heavier than pentane. The hydrocarbon gas composition from the secondary separator can have any suitable pressure, such as 0.01 psi (0.1 kPa) to 2 psi (14 kPa), or 0.1 psi (1 kPa) to 2 psi (14 kPa).

(16) The method can optionally include flowing the hydrocarbon gas composition from the secondary separator to a primary recovery separator. The method can include flowing the hydrocarbon gas from the primary recovery separator to the compressor. The primary recovery separator can include a two-phase separator or a three-phase separator. The primary recovery separator can include a heated separator or an unheated separator. The primary recovery separator can include a scrubber. The primary recovery separator can condense liquids from the hydrocarbon gas composition, can remove water from the hydrocarbon gas composition, or a combination thereof. The primary recovery separator can provide a low point to knock-out moisture and other condensate prior to compression. Liquids (e.g., hydrocarbons and water) can drain from the bottom of the primary recovery separator. The primary recovery separator can include a level sensor to detect a height of liquid such as water and/or hydrocarbons. The method can include flowing a gaseous hydrocarbon stream from the primary recovery separator (e.g., sales and/or flare gas). The primary recovery separator can optionally include a hydrocarbon gas output that can include oxygen that is removed from the hydrocarbon gas composition from the secondary separator.

(17) The compressor can include any suitable type of compressor. The compressor can include a piston compressor, a scroll compressor, or a combination thereof. The compressor can include an oilless compressor. The oilless compressor can include a crankcase that is free of oil that contacts material being compressed and is free of oil lubrication that requires regular changings. The method can be free of compression via a compressor that includes oil that contacts material being compressed and/or that includes oil lubrication that requires regular changings. The compressed mixture formed by the compressor can have any suitable pressure, such as a pressure of 100 psi (689 kPa) to 500 psi (3447 kPa), or 200 psi (1379 kPa) to 300 psi (2068 kPa). The compressed mixture formed by the compressor can have any suitable temperature, such as a temperature of 100° C. to 300° C., or 125° C. to 175° C.

(18) The cooling unit can be any suitable cooling unit that cools the compressed mixture. The cooling unit can include a heat exchanger, a refrigeration unit, an aftercooler, or a combination thereof. The cooling unit can include an air-cooled heat exchanger, a water-cooled heat exchanger, or a combination thereof. The cooling unit can include an air-cooled heat exchanger. The cooled composition can have any suitable pressure, such as a pressure of 100 psi (689 kPa) to 500 psi (3447 kPa), or 200 psi (1379 kPa) to 300 psi (2068 kPa). The cooled composition can have any suitable temperature that is less than the temperature of the compressed mixture formed by the compressor, such as a temperature of 0° C. to 80° C., or 10° C. to 40° C., or within 10° C. of ambient temperature.

(19) The method can optionally include separating the liquid hydrocarbons from any gaseous hydrocarbons and/or water in the cooled composition. The method can include flowing the cooled composition including liquid hydrocarbons to a secondary recovery separator, and the method can include flowing the liquid hydrocarbons from the secondary recovery separator to the primary separator. The secondary recovery separator can be any suitable separator. The secondary recovery separator can include a two-phase separator or a three-phase separator. The secondary recovery separator can include a heated separator or an unheated separator. The secondary recovery separator can include a separator column. The secondary recovery separator can include a level sensor to detect a height of liquid such as water and/or hydrocarbons. The method can include flowing a water stream from the secondary recovery separator. The method can include flowing a gaseous hydrocarbon stream from the secondary recovery separator (e.g., sales or flare gas). The method can include flowing the liquid hydrocarbons from the secondary recovery separator into the primary separator.

(20) Various aspects include a primary recovery separator with no secondary recovery separator. Various aspects include a secondary recovery separator with no primary recovery separator. Various aspects include both a primary recovery separator and a secondary recovery separator.

(21) The secondary separator accepts the crude liquid hydrocarbon stream from the primary separator, and outputs a liquid hydrocarbon stream and a gaseous hydrocarbon stream (e.g., rich gas). The liquid hydrocarbon stream is fed to the tank. The liquid hydrocarbon stream can be fed directly to a tank. The liquid hydrocarbon stream can be fed indirectly to the tank; for example, the liquid hydrocarbon stream can be fed to the primary separator which can perform separation operations on the liquid hydrocarbon stream before feeding it to the tank. The secondary separator can be any suitable separator. For example, the secondary separator can include a two-phase separator or a three-phase phase separator. The secondary separator can include a heated separator or an unheated separator. The secondary separator can include a heater-treater or a vapor recovery tower (VRT). The secondary separator can include a heater-treater. The secondary separator can operate at any suitable pressure, such as a pressure of 5 psi (34 kPa) to 80 psi (552 kPa), or 20 psi (138 kPa) to 50 psi (344 kPa).

(22) The liquid hydrocarbon stream flowed to the primary separator can include natural gas liquids. The liquid hydrocarbon stream flowed to the primary separator can include methane, ethane, propane, butane, pentane, hydrocarbons having 6 or more carbon atoms, or a combination thereof. The liquid hydrocarbon stream flowed to the primary separator can include <10% methane, up to 90% ethane, propane, butane, and pentane, and up to 10% hydrocarbons heavier than pentane. The liquid hydrocarbon stream flowed to the primary separator can have less than 10 ppm oxygen, such as greater than or equal to 0, 0.001, 0.01, or 0.1 ppm oxygen and less than or equal to 10 ppm, 9, 8, 7, 6, 5, 4, 3, 2, 1, or 0.5 ppm oxygen.

(23) Apparatus for Recycling Gaseous Hydrocarbons.

(24) Various aspects of the present invention provide an apparatus for performing aspects of the method of the present invention for recycling gaseous hydrocarbons from the secondary separator. The apparatus can be any suitable apparatus that can perform the method described herein. For example, the apparatus can include a compressor that accepts a hydrocarbon gas composition from a secondary separator. The secondary separator can accept a crude liquid hydrocarbon input stream from a primary separator. The primary separator can include a crude hydrocarbon input stream and include an output stream that includes the crude liquid hydrocarbon stream that is inputted to the secondary separator. The apparatus can include a cooling unit that accepts the compressed mixture from the compressor and that forms a cooled composition including liquid hydrocarbons. The apparatus also includes a flowline from the cooling unit for flowing liquid hydrocarbons to the primary separator. The apparatus, including the primary separator, secondary separator, compressor, cooler, optional primary recovery separator, optionally secondary recovery separator, or a combination thereof, can include can one or more suitable features as disclosed herein with respect to the method of the present invention for recycling gaseous hydrocarbons from the secondary separator.

(25) The apparatus can optionally further include a primary recovery separator that accepts the hydrocarbon gas composition from the secondary separator and that flows the hydrocarbon gas composition from the primary recovery separator to the compressor.

(26) The apparatus can optionally further include a secondary recovery separator that accepts the cooled composition including the liquid hydrocarbons and the outputs the liquid hydrocarbon stream to the primary separator.

(27) FIG. 1 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects. Apparatus 100 includes crude hydrocarbon input stream 105 which is fed to primary separator 110. The primary separator 110 outputs crude liquid hydrocarbon stream 111. The primary separator 110 optionally outputs hydrocarbon gas stream 112 (first stage gas). The primary separator 110 optionally outputs water stream 113. The crude liquid hydrocarbon stream 111 is fed to secondary separator 120. The secondary separator 120 outputs liquid hydrocarbon stream 121. The secondary separator 120 outputs hydrocarbon gas stream 122 (second stage gas). The secondary separator 120 optionally outputs water stream 123. Water streams 113 and 123 can be combined and sent to a tank for storage and or treatment. Liquid hydrocarbon stream 121 is fed to tank 130. The hydrocarbon gas stream 122 is flowed from the secondary separator 120 to an apparatus 140 for recycling gaseous hydrocarbons from the secondary separator according to the present invention. Apparatus 140 outputs liquid hydrocarbon stream 141 which is flowed to the primary separator 110. Various aspects of apparatus 140 are illustrated in detail in FIGS. 3 and 4.

(28) The method can include flowing a hydrocarbon gas composition from a first separator (e.g., a primary separator or a secondary separator) into a compressor unit to form a compressed mixture, wherein the first separator includes a crude hydrocarbon input stream. The method can include flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition including liquid hydrocarbons. The method can also include flowing the liquid hydrocarbons from the cooled composition into a second separator (e.g., a primary separator or a secondary separator), wherein the second separator includes an output stream including a liquid hydrocarbon stream that is inputted to the first separator. For example, the method of recycling gaseous hydrocarbons can include flowing a hydrocarbon gas composition from a secondary separator into a compressor unit to form a compressed mixture, wherein the secondary separator includes a crude hydrocarbon input stream. The method can include flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition including liquid hydrocarbons. The method can also include flowing the liquid hydrocarbons from the cooled composition into a primary separator, wherein the primary separator includes an output stream including a liquid hydrocarbon stream that is inputted to the secondary separator. For example, FIG. 2 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects. Apparatus 200 includes crude hydrocarbon input stream 205 which is fed to secondary separator 210 (e.g., a heater-treater). The secondary separator 210 outputs crude liquid hydrocarbon stream 211. The secondary separator 210 outputs hydrocarbon gas stream 212 (first stage gas). The secondary separator 210 optionally outputs water stream 213. The hydrocarbon gas stream 212 is fed to apparatus 240 for recycling gaseous hydrocarbons according to the present invention, shown in greater detail in FIGS. 3 and 4. Apparatus 240 outputs liquid hydrocarbon stream 241 which is flowed to the primary separator 220. Primary separator 220 optionally outputs hydrocarbon gas stream 222. Primary separator 220 optionally outputs a water stream (not shown). Primary separator 220 outputs a liquid hydrocarbon stream 221 which is combined with crude hydrocarbon input stream 205 and fed back to the secondary separator 210. The secondary separator outputs liquid hydrocarbon stream 211 which is fed to tank 230. Various aspects of apparatus 240 are illustrated in detail in FIGS. 3 and 4.

(29) FIG. 3 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects. Apparatus 300 includes compressor 310, which is fed by the hydrocarbon gas stream 305 from the separator (e.g., from a primary or secondary separator). The compressor outputs compressed mixture 311, which is fed to cooling unit 320. Cooling unit 320 forms a cooled composition including liquid hydrocarbons 321.

(30) FIG. 4 illustrates a method and apparatus for recycling gaseous hydrocarbons, in accordance with various aspects. Apparatus 400 includes a primary recovery separator 410, which is fed by the hydrocarbon gas stream 405 from the separator (e.g., from a primary or secondary separator). Primary recovery separator outputs hydrocarbon gas composition 411. Primary recovery separator can optionally output water stream 413 and hydrocarbon gas stream 412. Hydrocarbon gas composition 411 is fed to compressor 420, which forms compressed mixture 421. The compressed mixture is fed to cooling unit 430, which forms cooled composition 431 including liquid hydrocarbons. The cooled composition including liquid hydrocarbons 431 is fed to secondary recovery separator 440. Secondary recovery separator 440 forms a liquid composition including the liquid hydrocarbons 441. Secondary recovery separator 440 optionally forms hydrocarbon gas stream 442 and water stream 443.

(31) The terms and expressions that have been employed are used as terms of description and not of limitation, and there is no intention in the use of such terms and expressions of excluding any equivalents of the features shown and described or portions thereof, but it is recognized that various modifications are possible within the scope of the aspects of the present invention. Thus, it should be understood that although the present invention has been specifically disclosed by specific aspects and optional features, modification and variation of the concepts herein disclosed may be resorted to by those of ordinary skill in the art, and that such modifications and variations are considered to be within the scope of aspects of the present invention.

Exemplary Aspects

(32) The following exemplary aspects are provided, the numbering of which is not to be construed as designating levels of importance:

(33) Aspect 1 provides a method of recycling gaseous hydrocarbons, the method comprising:

(34) flowing a hydrocarbon gas composition from a secondary separator into a compressor unit to form a compressed mixture, wherein the secondary separator comprises a crude liquid hydrocarbon input stream from a primary separator;

(35) flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition comprising liquid hydrocarbons; and

(36) flowing the liquid hydrocarbons from the cooled composition into the primary separator, wherein the primary separator comprises a crude hydrocarbon input stream and comprises an output stream comprising the crude liquid hydrocarbon stream that is inputted to the secondary separator.

(37) Aspect 2 provides the method of Aspect 1, wherein the crude hydrocarbon input stream is from an oil well at an on-shore oil recovery or production facility.

(38) Aspect 3 provides the method of Aspect 1, wherein the crude hydrocarbon input stream is from an oil well at an off-shore oil recovery or production facility.

(39) Aspect 4 provides the method of any one of Aspects 1-3, wherein the crude hydrocarbon input stream has a pressure of 10 psi (70 kPa) to 500 psi (3447 kPa).

(40) Aspect 5 provides the method of any one of Aspects 1-4, wherein the crude hydrocarbon input stream has a pressure of 50 psi (345 kPa) to 100 psi (689 kPa).

(41) Aspect 6 provides the method of any one of Aspects 1-5, wherein the primary separator comprises a two-phase separator or a three-phase separator.

(42) Aspect 7 provides the method of any one of Aspects 1-6, wherein the primary separator comprises a heated separator.

(43) Aspect 8 provides the method of any one of Aspects 1-6, wherein the primary separator comprises an unheated separator.

(44) Aspect 9 provides the method of any one of Aspects 1-8, wherein the primary separator comprises a two-phase separator.

(45) Aspect 10 provides the method of any one of Aspects 1-9, wherein the primary separator comprises the crude liquid hydrocarbon output stream and a crude hydrocarbon gaseous output stream.

(46) Aspect 11 provides the method of any one of Aspects 1-10, wherein the hydrocarbon gas composition from the secondary separator comprises methane, ethane, propane, butane, hydrocarbons having 5 or more carbon atoms, or a combination thereof.

(47) Aspect 12 provides the method of any one of Aspects 1-11, wherein the hydrocarbon gas composition from the secondary separator is less than 50 mole % methane and is predominantly ethane, propane, and butane.

(48) Aspect 13 provides the method of any one of Aspects 1-12, wherein the hydrocarbon gas composition from the secondary separator has a pressure of 5 psi (34 kPa) to 80 psi (552 kPa).

(49) Aspect 14 provides the method of any one of Aspects 1-13, wherein the hydrocarbon gas composition from the secondary separator has a pressure of 20 psi (138 kPa) to 50 psi (344 kPa).

(50) Aspect 15 provides the method of any one of Aspects 1-14, further comprising flowing the hydrocarbon gas composition from the secondary separator to a primary recovery separator, and flowing the hydrocarbon gas composition from the primary recovery separator to the compressor.

(51) Aspect 16 provides the method of Aspect 15, wherein the primary recovery separator comprises a two-phase separator or a three-phase separator.

(52) Aspect 17 provides the method of any one of Aspects 15-16, wherein the primary recovery separator comprises a heated separator.

(53) Aspect 18 provides the method of any one of Aspects 15-16, wherein the primary recovery separator comprises an unheated separator.

(54) Aspect 19 provides the method of any one of Aspects 15-18, wherein the primary recovery separator comprises a scrubber.

(55) Aspect 20 provides the method of any one of Aspects 15-19, wherein the primary recovery separator condenses liquids from the hydrocarbon gas composition, removes water from the hydrocarbon gas composition, or a combination thereof.

(56) Aspect 21 provides the method of any one of Aspects 1-20, wherein the compressor comprises a piston compressor, a scroll compressor, or a combination thereof.

(57) Aspect 22 provides the method of any one of Aspects 1-21, wherein the compressor comprises an oilless compressor, wherein the oilless compressor comprises a crankcase that is free of oil that contacts material being compressed and is free of oil lubrication that requires regular changings.

(58) Aspect 23 provides the method of any one of Aspects 1-22, wherein the method is free of compression via a compressor that comprises oil that contacts material being compressed and/or that comprises oil lubrication that requires regular changings.

(59) Aspect 24 provides the method of any one of Aspects 1-23, wherein the compressed mixture has a pressure of 100 psi (689 kPa) to 500 psi (3447 kPa).

(60) Aspect 25 provides the method of any one of Aspects 1-24, wherein the compressed mixture has a pressure of 200 psi (1379 kPa) to 300 psi (2068 kPa).

(61) Aspect 26 provides the method of any one of Aspects 1-25, wherein the compressed mixture has a temperature of 100° C. to 300° C.

(62) Aspect 27 provides the method of any one of Aspects 1-26, wherein the compressed mixture has a temperature of 125° C. to 175° C.

(63) Aspect 28 provides the method of any one of Aspects 1-27, wherein the cooling unit comprises a heat exchanger, a refrigeration unit, an aftercooler, or a combination thereof.

(64) Aspect 29 provides the method of any one of Aspects 1-28, wherein the cooling unit comprises an air-cooled heat exchanger, a water-cooled heat exchanger, or a combination thereof.

(65) Aspect 30 provides the method of any one of Aspects 1-29, wherein the cooling unit comprises an air-cooled heat exchanger.

(66) Aspect 31 provides the method of any one of Aspects 1-30, wherein the cooled composition has a pressure of 100 psi (689 kPa) to 500 psi (3447 kPa).

(67) Aspect 32 provides the method of any one of Aspects 1-31, wherein the cooled composition has a pressure of 200 psi (1379 kPa) to 300 psi (2068 kPa).

(68) Aspect 33 provides the method of any one of Aspects 1-32, wherein the cooled composition has a temperature of 0° C. to 80° C.

(69) Aspect 34 provides the method of any one of Aspects 1-33, wherein the cooled composition has a temperature of 10° C. to 40° C.

(70) Aspect 35 provides the method of any one of Aspects 1-34, wherein recovering the liquid hydrocarbons comprises separating the liquid hydrocarbons from any gaseous hydrocarbons and/or water in the cooled composition.

(71) Aspect 36 provides the method of any one of Aspects 1-35, further comprising flowing the cooled composition comprising liquid hydrocarbons to a secondary recovery separator before flowing the liquid hydrocarbons into the primary separator.

(72) Aspect 37 provides the method of Aspect 36, wherein the secondary recovery separator comprises a two-phase separator or a three-phase separator.

(73) Aspect 38 provides the method of any one of Aspects 36-37, wherein the secondary recovery separator comprises a heated separator.

(74) Aspect 39 provides the method of any one of Aspects 36-37, wherein the secondary recovery separator comprises an unheated separator.

(75) Aspect 40 provides the method of any one of Aspects 36-39, wherein the secondary recovery separator comprises a separator column.

(76) Aspect 41 provides the method of any one of Aspects 36-40, wherein the secondary recovery separator comprises a level sensor.

(77) Aspect 42 provides the method of any one of Aspects 36-41, wherein the method further comprises flowing a water stream from the secondary recovery separator.

(78) Aspect 43 provides the method of any one of Aspects 36-42, wherein the method further comprises flowing a gaseous hydrocarbon stream from the secondary recovery separator.

(79) Aspect 44 provides the method of any one of Aspects 1-43, wherein the secondary separator comprises a two-phase separator or a three-phase separator.

(80) Aspect 45 provides the method of any one of Aspects 1-44, wherein the secondary separator comprises a heated separator.

(81) Aspect 46 provides the method of any one of Aspects 1-44, wherein the secondary separator comprises an unheated separator.

(82) Aspect 47 provides the method of any one of Aspects 1-46, wherein the secondary separator comprises a heater-treater or a vapor recovery tower (VRT).

(83) Aspect 48 provides the method of any one of Aspects 1-47, wherein the secondary separator comprises a heater-treater.

(84) Aspect 49 provides the method of any one of Aspects 1-48, wherein the secondary separator feeds a liquid hydrocarbon composition to a tank at a pressure of 5 psi (34 kPa) to 80 psi (552 kPa).

(85) Aspect 50 provides the method of any one of Aspects 1-49, wherein the secondary separator feeds a liquid hydrocarbon composition to a tank at a pressure of 20 psi (138 kPa) to 50 psi (344 kPa).

(86) Aspect 51 provides the method of any one of Aspects 1-50, wherein the liquid hydrocarbons flowed into the primary separator comprise natural gas liquids.

(87) Aspect 52 provides the method of any one of Aspects 1-51, wherein the liquid hydrocarbons flowed into the primary separator comprise a stream comprising methane, ethane, propane, butane, pentane, hydrocarbons having 6 or more carbon atoms, or a combination thereof.

(88) Aspect 53 provides the method of any one of Aspects 1-52, wherein the liquid hydrocarbons flowed into the primary separator comprise a stream comprising <10% methane, up to 90% ethane, propane, butane, and pentane, and up to 10% hydrocarbons heavier than pentane.

(89) Aspect 54 provides the method of any one of Aspects 1-53, wherein the liquid hydrocarbons flowed into the primary separator comprise a stream having less than 10 ppm oxygen.

(90) Aspect 55 provides a method of recycling gaseous hydrocarbons, the method comprising:

(91) flowing a hydrocarbon gas composition from a heater-treater into a compressor unit to form a compressed mixture, wherein the heater-treater comprises a crude liquid hydrocarbon input stream from a two-phase separator;

(92) flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition comprising liquid hydrocarbons; and

(93) flowing the liquid hydrocarbons from the cooled composition into the two-phase separator, wherein the two-phase separator comprises a crude hydrocarbon input stream and comprises an output stream comprising the crude liquid hydrocarbon stream that is inputted to the heater-treater;

(94) or

(95) the method comprising:

(96) flowing a hydrocarbon gas composition from a first separator (e.g., a primary separator or a secondary separator) into a compressor unit to form a compressed mixture, wherein the first separator comprises a crude hydrocarbon input stream;

(97) flowing the compressed mixture into a cooling unit to cool the compressed mixture, to form a cooled composition comprising liquid hydrocarbons; and

(98) flowing the liquid hydrocarbons from the cooled composition into a second separator (e.g., a primary separator or a secondary separator), wherein the second separator comprises an output stream comprising a liquid hydrocarbon stream that is inputted to the first separator.

(99) Aspect 56 provides an apparatus for performing the method of any one of Aspects 1-55.

(100) Aspect 57 provides an apparatus for recycling gaseous hydrocarbons, the apparatus comprising:

(101) a compressor that accepts a hydrocarbon gas composition from a secondary separator, wherein the secondary separator accepts a crude liquid hydrocarbon input stream from a primary separator, wherein the primary separator comprises a crude hydrocarbon input stream and comprises an output stream that comprises the crude liquid hydrocarbon stream that is inputted to the secondary separator;

(102) a cooling unit that accepts the compressed mixture from the compressor and that forms a cooled composition comprising liquid hydrocarbons; and

(103) a flowline from the cooling unit for flowing the liquid hydrocarbons to the primary separator.

(104) Aspect 58 provides the apparatus of Aspect 57, further comprising a primary recovery separator that accepts the hydrocarbon gas composition from the secondary separator and that flows the hydrocarbon gas composition from the primary recovery separator to the compressor.

(105) Aspect 59 provides the apparatus of any one of Aspects 57-58, further comprising a secondary recovery separator that accepts the cooled composition comprising the liquid hydrocarbons and that outputs the liquid hydrocarbon stream to the primary separator.

(106) Aspect 60 provides the apparatus or method of any one or any combination of Aspects 1-59 optionally configured such that all elements or options recited are available to use or select from.