DEVICE FOR EXTRACTING GAS FROM A DRILLING FLUID FOR A SYSTEM FOR CONDUCTING SUBTERRANEAN DRILLING OPERATIONS

A gas extraction device includes a housing having a drilling fluid inlet and a drilling fluid outlet. A drilling fluid path can extend between the drilling fluid inlet to the drilling fluid outlet. Moreover, a plurality of drilling fluid disruptors, e.g., baffles, can be installed along the drilling fluid path. The drilling fluid disruptors liberate entrapped gas in the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

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Description
CROSS REFERENCE TO RELATED APPLICATION(S)

This application claims priority under 35 U.S.C. § 119(e) to U.S. Patent Application No. 62/865,691, entitled “DEVICE FOR EXTRACTING GAS FROM A DRILLING FLUID FOR A SYSTEM FOR CONDUCTING SUBTERRANEAN DRILLING OPERATIONS,” by Albert NEUBERT and Jeremy WHITT, filed Jun. 24, 2019, which application is assigned to the current assignee hereof and incorporated herein by reference in its entirety.

TECHNICAL FIELD

The present invention relates, in general, to drilling operations and more specifically, to a device for extracting gas from a drilling fluid for a drilling rig.

BACKGROUND

Hundreds of billions of dollars are spent worldwide for subterranean drilling. Much of this activity is conducted on drilling platforms. For example, these drilling platforms may include fixed platforms, compliant towers, semi-submersible platforms, jack-up drilling rigs, drill ships, floating productions systems, tension-leg platforms, gravity-based structures, and spar platforms. Regardless of the type of platform, these are complex operations that generally require the use of drilling rigs in order to locate and recover oil.

Accordingly, the exploration and production of natural resources continues to demand improvements.

SUMMARY

In accordance with an aspect of the disclosure, a device is provided that can include a housing having an exterior wall, a housing having a drilling fluid inlet and a drilling fluid outlet, a drilling fluid path extending between the drilling fluid inlet to the drilling fluid outlet; and a plurality of drilling fluid disruptors installed along the drilling fluid path, wherein the drilling fluid disruptors liberate entrapped gas in the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

In accordance with an aspect of the disclosure, a system is provided that can include at least one drill having a drill string and a drill bit, at least one pump for providing a drilling fluid to the drill string and the drill bit, the pump having an in-line and a return line, a bypass valve installed along the return line, and a gas extraction device connected to the bypass valve, wherein the bypass valve can be selectively opened to provide drilling fluid to the gas extraction device, wherein the gas extraction device tumbles drilling fluid within a housing of the gas extraction device to extract entrapped gas from the drilling fluid.

In accordance with an aspect of the disclosure, a method is provided that can include operations of bypassing a portion of a drilling fluid from a return line to a gas extraction device, tumbling the drilling fluid within the gas extraction device to release entrapped gas from the drilling fluid, and transmitting the entrapped gas to a test station for analysis.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure may be better understood, and its numerous features and advantages made apparent to those skilled in the art by referencing the accompanying drawings.

FIG. 1 includes an illustration of a block diagram of a system for conducting subterranean operations in accordance with an embodiment.

FIG. 2 includes an illustration of a front plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 3 includes an illustration of a side plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 4 includes an illustration of a top plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 5 includes an illustration of a bottom plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 6 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment taken along line 6-6 in FIG. 4.

FIG. 7 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 8 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 9 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 10 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 11 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 12 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 13 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 14 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 15 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 16 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 17 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 18 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 19 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 20 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 21 includes an illustration of a front plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 22 includes an illustration of a side plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 23 includes an illustration of a top plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 24 includes an illustration of a bottom plan view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment.

FIG. 25 includes an illustration of a cross-section view of a device for extracting gas from a drilling fluid for a system for conducting subterranean operations in accordance with an embodiment taken along line 25-25 in FIG. 23.

FIG. 26 includes an illustration of a flow chart depicting a method of extracting gas from a drilling fluid while conducting subterranean operations in accordance with an embodiment.

 DETAILED DESCRIPTION

The following is generally directed to a device, system, and method for extracting gas from a drilling fluid while conducting a subterranean operation.

Embodiments are directed to a device for extracting gas from a drilling fluid used by system for conduction subterranean operations. The gas extraction device may be connected to a drilling fluid return line in the system via a bypass valve. The bypass valve can bypass a portion of the drilling fluid, i.e., used drilling fluid, from the return line into the gas extraction device. The gas extraction device can tumble the drilling fluid therein to liberate, or release, gas from the drilling fluid. The liberated gas can be transmitted to a test system for analysis and speciation.

Referring initially to FIG. 1, a system for conducting subterranean drilling operations is illustrated and is generally designated 100. The system 100 can include a drill rig 102 having a drill string 104 and a drill bit 106 coupled to the drill string 104. A drilling fluid pump 108 can be in fluid communication with the drill rig 102 via an in-line 110. As shown, a supply reservoir 112 can be connected to the drilling fluid pump 108. The supply reservoir 112 can contain drilling fluid, a.k.a., drilling mud, and the drilling fluid can be pumped to the drill rig 102 by the drilling fluid pump 108 via the in-line 110.

The use of the word “about”, “approximately”, or “substantially” is intended to mean that a value of a parameter is close to a stated value or position. However, minor differences may prevent the values or positions from being exactly as stated. Thus, differences of up to ten percent (10%) for the value are reasonable differences from the ideal goal of exactly as described. A significant difference can be when the difference is greater than ten percent (10%).

FIG. 1 also shows that a catch reservoir 114 can be in fluid communication with the drill rig 102 via a return line 116. A bypass valve 118 can be installed along the return line 116. Further, a gas extraction device 120 can be connected to the bypass valve 118 and a test system 122 can be connected to the gas extraction device 120. When the bypass valve 118 is opened, a portion of the drilling fluid in the return line 116 can be bypassed to the gas extraction device 120. The gas extraction device 120 can tumble the drilling fluid therein in order to liberate, or extract, gas from the drilling fluid. The extracted gas can be pumped to the test system 122 for analysis and speciation by a gas pump 124 installed between the gas extraction device 120 and the test system 122.

Referring now to FIG. 2 through FIG. 6, a gas extraction device is shown and is generally designated 200. As illustrated the gas extraction device 200 can include a generally cylindrical housing 202 having a top end 204 and a bottom end 206. The top end 204 of the housing 202 can include a drilling fluid inlet 208 that can be coupled to a bypass valve, described above, and the bottom end 206 of the housing 202 can include a drilling fluid outlet 210 that can be coupled to a catch reservoir, described above. The top end 204 of the housing 202 can also include a gas outlet 212 that can be connected to the test system, described above. Any gas that is liberated, or extracted, from the drilling fluid 214 as it passes through the gas extraction device 200 can exit the gas extraction device 200 and can be pumped to the test system by the gas pump, described above.

FIG. 6 indicates that the housing 202 of the gas extraction device 200 can include an outer wall 216 and a plurality of drilling fluid disrupters 218 can extend from the outer wall 216 of the housing 202 of the gas extraction device 200 in a generally inward and downward direction. Specifically, the plurality of drilling fluid disrupters 218 can include a first baffle 220, a second baffle 222, a third baffle 224, a fourth baffle 226, and a fifth baffle 228. Moving from the top 204 of the housing 202 of the gas extraction device 200 to the bottom 206 of the housing 202 of the gas extraction device 200, the first baffle 220 is closest to the drilling fluid inlet 208. The second baffle 222 is below the first baffle 220. The third baffle 224 is below the second baffle 222. The fourth baffle 226 is below the third baffle 224. The fifth baffle 228 is below the fourth baffle 226. In a particular aspect, each baffle 220, 222, 224, 226, 228 can be a semi-circular plate installed at an angle within the gas extraction device 200.

In a particular aspect, the first baffle 220, the second baffle 222, the third baffle 224, the fourth baffle 226, and the fifth baffle 228 can form an angle, α, with respect to a horizontal axis 229 that is perpendicular to a longitudinal axis 231 of the housing 202 of the gas extraction device 200. As indicated in FIG. 6, α can be the same for each of the baffles 220, 222, 224, 226, 228. In one aspect, α can be greater than or equal to 5°. Further, α can be greater than or equal to 7.5°, such as greater than or equal to 10°, greater than or equal to 12.5°, or greater than or equal to 15°. Still in another aspect, α can be less than or equal to 30°, such as less than or equal to 27.5°, less than or equal to 25°, less than or equal to 22.5°, less than or equal to 20°, or less than or equal to 17.5°. It is to be understood that α can be within a range between, and including, any of the values of α described herein.

As illustrated in FIG. 6, each of the baffles 220, 222, 224, 226, 228 can include a generally flat base 230 having a proximal end 232 extending from, and adjacent to, the sidewall 216 of the housing 202 of the gas extraction device 200 and a distal end 234 that extends into the interior space 236 bound by the sidewall 216 of the housing 202. The distal end 234 of each baffle 220, 222, 224, 226, 228 can include a tail 238 that extends from the base 230. In one aspect, as illustrated in FIG. 6, each tail 238 can extend in a generally upward direction from the distal end 234 of the base 230 of each baffle 220, 222, 224, 226, 228 and can be substantially parallel to the longitudinal axis 231 of the gas extraction device 200. As shown in FIG. 6, each tail 238 can be straight and each tail can include a height, HT, measured from the lowermost portion of the tail 238 to the uppermost portion of the tail 238. In the aspect shown in FIG. 6, HT is the same for the tail 238 of each baffle 220, 222, 224, 226, 228. For example, HT can be than or equal to 5 inches. Further, HT can be less than or equal to 4.5 inches, such as less than or equal to 4.0 inches, less than or equal to 3.5 inches, less than or equal to 3.0 inches, or less than or equal to 2.5 inches. In another aspect, HT is greater than or equal to 0.5 inches, such as greater than or equal to 0.75 inches, greater than or equal to 1.0 inches, greater than or equal to 1.5 inches, or greater than or equal to 2.0 inches. It is to be understood that HT can be within a range between and including any of the values of HT described herein.

FIG. 6 shows that the gas extraction device 200 can also include a splash plate 240 adjacent to, or closest to, the drilling fluid outlet 210. The splash plate 240 is between the fifth baffle 228 and the drilling fluid outlet 210 and helps guide the drilling fluid 214 to the drilling fluid outlet 210. In particular, the splash plate 240 can include a generally flat base plate 242 that can include proximal end 244 extending from, and adjacent to, the outer wall 216 of the housing 202 of the gas extraction device 200. Further, the generally flat base plate 242 of the splash plate 240 can include a distal end 246 that extends into the interior space 236 of the housing 202 of the gas extraction device 200. FIG. 6 further shows that the splash plate 240 can include a tail 248 that extends in a generally downward direction from the distal end 246 of the base plate 242 of the splash plate 240. Further, the splash plate 240 can also include a central support structure 250 that can be part of the drilling fluid outlet 210. As illustrated, an S-trap 252 can be established between the tail 248 of the splash plate 240 and the central support structure 250 of the splash plate 240 adjacent to the drilling fluid outlet 210. The S-trap 252 can substantially prevent, or minimize, any gases liberated, or extracted, from the drilling fluid 214 from exiting the gas extraction device 200 via the drilling fluid outlet 210.

Still referring to FIG. 6, the gas extraction device 200 can include an impeller 260 placed in the fluid path between the drilling fluid inlet 208 and the drilling fluid outlet 210. The impeller 260 can include a paddle wheel 262 and can include a central hub 264 installed on a pump drive shaft 266. The pump drive shaft 266 can be coupled to a gas pump (not shown in FIG. 6). As shown, a plurality of paddles 268 can extend from the central hub 264 of the paddle wheel 262. During operation of the gas extraction device 200, as the drilling fluid 214 flows through the gas extraction device 200 along the fluid path between the drilling fluid inlet 208 and the drilling fluid outlet 210, the drilling fluid 214 can act on the paddles of the paddle wheel 262 and can cause the paddle wheel 262 to rotate. As the paddle wheel 262 rotates, the pump drive shaft 266 can rotate and can drive the gas pump connected thereto in order to pump gas out of, and away from, the gas extraction device 200 where the gas can be collected for analysis and speciation.

In a particular aspect, the housing 202 of the gas extraction device 200 can have an overall height, HO, measured from a top of the housing 202 to a bottom of the housing 202 and HO can be less than or equal to 5 feet. Further, HO can be less than or equal to 4.5 feet, such as less than or equal to 4.0 feet, less than or equal to 3.5 feet, or less than or equal to 3.0 feet. In another aspect, HO can be greater than or equal to 1.5 feet, such as greater than or equal to 2.0 feet, or greater than or equal to 2.5 feet. It is to be understood that HO can be within a range between, and including, any of maximum and minimum values of HO described herein.

In another aspect, the housing 202 of the gas extraction device 200 can have an overall diameter, DO, and DO can be less than or equal to 3.0 feet. Moreover, DO can be less than or equal to 2.5 feet, such as less than or equal to 2.0 feet, or less than or equal to 1.5 feet. In another aspect, DO can be greater than or equal to 0.5 feet, such as greater than or equal to 1.0 feet, or greater than or equal to 1.25 feet. It is to be understood that DO can be within a range between, and including, any of the maximum and minimum values of DO described herein.

In another aspect, the housing 202 of the gas extraction device 200 can have an internal volume that is less than or equal to 15.0 cubic feet. Further, the internal volume of the housing 202 can be less than or equal to 12.5 cubic feet, such as less than or equal to 10.0 cubic feet, or less than or equal to 7.5 cubic feet. In still another aspect, the internal volume of the housing 202 can be greater than or equal to 2.0 cubic feet, such as greater than or equal to 3.0 cubic feet, greater than or equal to 4.0 cubic feet, greater than or equal to 5.0 cubic feet, or greater than or equal to 6.0 cubic feet. It is to be understood that the internal volume of the housing 202 can be within a range between, and including, any of the maximum and minimum values of the internal volume described herein.

In another aspect of a gas extraction device 700, illustrated in FIG. 7, the first baffle 720 can form a first angle, α1, with respect to the outer wall 716 of the housing 702 of the gas extraction device 200. The second baffle 722 can form a second angle, α2, with respect to the outer wall 716 of the housing 702 of the gas extraction device 200. The third baffle 724 can form a third angle, α3, with respect to the outer wall 716 of the housing 702 of the gas extraction device 200. The fourth baffle 726 can form a fourth angle, α4, with respect to the outer wall 716 of the housing 702 of the gas extraction device 200. Further, the fifth baffle 728 can form a fifth angle, α5, with respect to the outer wall 716 of the housing 702 of the gas extraction device 200.

In this aspect, as illustrated in FIG. 7, the angle, α, can be different for each baffle 720, 722, 724, 726, 728. In other words, α1 can be different from α2, which can be different from α3, which can be different from α4, which can be different from α5. Specifically, α2 can be greater than α1, α3 can be greater than α2, α4 can be greater than α3, and α5 can be greater than α4. Moreover, α can increase from the uppermost baffle, i.e., the first baffle 720 to the lowermost baffle, i.e., the fifth baffle 728. In one aspect, the increase in α can be greater than or equal to 1.0°. Additionally, the increase in α can be greater than or equal to 1.5°, such as greater than or equal to 2.0°, or greater than or equal to 2.5°. Further, the increase in α can be less than or equal to 10°, such as less than or equal to 7.5°, or less than or equal to 5.0°. It is to be understood that the increase in α can be within a range between, and including, any of the values of the increase in α described herein. It is also to be understood that the increase in α is progressive. In other words, α2=α1+the increase in α, α3=α2+the increase in α, α4=α3+the increase in α, and α5=α4+the increase in α.

The gas extraction device 700 illustrated in FIG. 7 shows that the height of the tail 738 of each baffle 720, 722, 724, 726, 728 can be different. Specifically, height of each tail 738 can decrease from the uppermost baffle, i.e., the first baffle 720, to the lowermost baffle, i.e., the fifth baffle 728. In other words, the tail 738 of the second baffle 722 can be shorter than the tail 738 of the first baffle 720. Moreover, the tail 738 of the third baffle 724 can be shorter than the tail 738 of the second baffle 722. The tail 738 of the fourth baffle 726 can be shorter than the tail 738 of the third baffle 724. And, the tail 738 of the fifth baffle 728 can be shorter than the tail 738 of the fourth baffle 726. In a particular aspect, the decrease in HT can be greater than or equal to 0.5 inches. Moreover, the decrease in HT can be greater than or equal to 0.75 inches, such as greater than or equal to 1.0 inches, greater than or equal to 1.25 inches, or greater than or equal to 1.5 inches. Additionally, the decrease in HT can be less than or equal to 2.5 inches, such as less than or equal to 2.25 inches, less than or equal to 2.0 inches, or less than or equal to 1.75 inches. It is to be understood that the decrease in HT can be within a range between, and including, any of the values of the decrease in HT described herein. It is also to be understood that the decrease in HT is progressive. In other words, HT of the tail 738 of the second baffle 722 can be equal to HT of the tail 738 of the first baffle 720 minus the decrease in HT. Further, HT of the tail 738 of the third baffle 724 can be equal to HT of the tail 738 of the second baffle 722 minus the decrease in HT. HT of the tail 738 of the fourth baffle 726 can be equal to HT of the tail 738 of the third baffle 724 minus the decrease in HT. Finally, HT of the tail 738 of the fifth baffle 728 can be equal to HT of the tail 738 of the fourth baffle 726 minus the decrease in HT. It can be appreciated that if the gas extraction device 700 were to include more than five baffles as shown, the pattern outlined above with respect to the decrease in HT could continue to the lowermost baffle.

FIG. 8 depicts another gas extraction device 800 in which the tail 838 of each baffle 820, 822, 824, 826, 828 forms an acute angle with respect to the base 830 of each baffle 820, 822, 824, 826, 828. FIG. 9 depicts a gas extraction device 900 in which the tail 938 of each baffle 920, 922, 924, 926, 928 forms a right angle with respect to the base 930 of each baffle 920, 922, 924, 926, 928. FIG. 10 shows a gas extraction device 1000 in which the tail 1038 of each baffle 1020, 1022, 1024, 1026, 1028 forms an obtuse angle with respect to the base 1030 of each baffle 1020, 1022, 1024, 1026, 1028. FIG. 11 illustrates a gas extraction device 1100 in which the tail 1138 of the first baffle 1120 forms an acute angle with respect to the base 1130 of the first baffle 1120 and the tails 1138 of the remaining baffles 1122, 1124, 1126, 1128 form right angles with respect to the bases 1130 of those baffles 1122, 1124, 1126, 1128. FIG. 12 illustrates a gas extraction device 1200 in which the tail 1238 of the first baffle 1220 forms a right angle with respect to the base 1230 of the first baffle 1220 and the tails 1238 of the remaining baffles 1222, 1224, 1226, 1228 form acute angles with respect to the bases 1230 of those baffles 1222, 1224, 1226, 1228. FIG. 13 illustrates a gas extraction device 1300 in which the tail 1338 of the first baffle 1320 forms an acute angle with respect to the base 1330 of the first baffle 1320 and the tails 1338 of the remaining baffles 1322, 1324, 1326, 1328 form obtuse angles with respect to the bases 1330 of those baffles 1322, 1324, 1326, 1328. FIG. 14 illustrates a gas extraction device 1400 in which the tail 1438 of the first baffle 1420 forms a right angle with respect to the base 1430 of the first baffle 1420 and the tails 1438 of the remaining baffles 1422, 1424, 1426, 1428 form obtuse angles with respect to the bases 1430 of those baffles 1422, 1424, 1426, 1428. It can be appreciated the height of each tail in the embodiments illustrated in FIG. 8 through 14 can be the same, as shown, or they can be different, as described above. Further, the tails of each baffle can alternate between an acute angle and an obtuse angle, an acute angle and a right angle, an obtuse angle and an acute angle, an obtuse angle and a right angle, a right angle and an acute angle, and a right angle and an obtuse angle.

FIG. 15 through FIG. 18 illustrate gas extraction devices that include baffles having curved tails. For example, the gas extraction device 1500 shown in FIG. 15 indicates that each baffle 1520, 1522, 1524, 1526, 1528 can include a tail 1538 that curves away from the baffle 1520, 1522, 1524, 1526, 1528, i.e., away from the base 1530 of each baffle 1520, 1522, 1524, 1526, 1528 and away from the central longitudinal axis of the gas extraction device 1500. The gas extraction device 1600 shown in FIG. 16 indicates that each baffle 1620, 1622, 1624, 1626, 1628 can include a tail 1638 that curves toward the baffle 1620, 1622, 1624, 1626, 1628, i.e., toward the base 1630 of each baffle 1620, 1622, 1624, 1626, 1628 and toward the central longitudinal axis of the housing 1602 of the gas extraction device 1600. The gas extraction device 1700 illustrated in FIG. 17 indicates that the first baffle 1720 can include a tail 1738 that curves toward the first baffle 1720, i.e., toward the base 1730 of the first baffle 1720 and toward the central longitudinal axis of the gas extraction device 1700. The remaining baffles 1722, 1724, 1726, 1728, below the first baffle 1720, can each include a tail 1738 that curves away from the baffle 1722, 1724, 1726, 1728, i.e., away from the base 1730 of each baffle 1722, 1724, 1726, 1728 and away from the central longitudinal axis of the gas extraction device 1700. Further, the gas extraction device 1800 illustrated in FIG. 18 indicates that the first baffle 1820 can include a tail 1838 that curves away from the first baffle 1820, i.e., away from the base 1830 of the first baffle 1820 and away from the central longitudinal axis of the gas extraction device 1800. The remaining baffles 1822, 1824, 1826, 1828, below the first baffle 1820, can each include a tail 1838 that curves toward the baffle 1822, 1824, 1826, 1828, i.e., toward the base 1830 of each baffle 1822, 1824, 1826, 1828 and toward the central longitudinal axis of the gas extraction device 1800. It can be appreciated the height of each tail in the embodiments illustrated in FIG. 15 through 18 can be different, as shown, or they can be the same. Further, alternating tails can be curved away from the baffle and toward the baffle or toward the baffle and away from the baffle.

Referring now to FIG. 19, a gas extraction device 1900 is illustrated. One or more of the baffles 1920, 1922, 1924, 1926, 1928 can include a surface feature, e.g., a rib 1970, extending in a generally upward direction from the base 1930 of the baffle 1920, 1922, 1924, 1926, 1928. The rib 1970 can have a generally semi-circular cross section, a triangular cross section, or any other shape that will promote tumbling of the drilling fluid (not shown) as the drilling fluid flows across the baffles 1920, 1922, 1924, 1926, 1928.

FIG. 20 illustrates a gas extraction device 2000 in which the first baffle 1920 does not include a tail, while the remaining baffles, i.e., the second through fifth baffles, 2022, 2024, 2026, 2028 each include a tail 2038. In other words, the distal end of the first baffle 2020 is configured without any tail or end feature in order to allow the drilling fluid to flow directly off of the first baffle 2020. This design may limit splashing of the drilling fluid as it exits the first baffle 2020. Moreover, a portion of the fluid outlet 2010 opposite the central support structure 2050 can be shortened (e.g., the height thereof) or eliminated, as shown, in order to further promote flow of the drilling fluid out of the gas extraction device 2000 via the drilling fluid outlet 2010.

In this aspect, the drilling fluid disruptor comprises a series of baffles 2020, 2022, 2024, 2026, 2028 and a first baffle 2020 in the series of baffles 2020, 2022, 2024, 2026, 2028 comprises a base having an unencumbered distal end and each subsequent baffle 2022, 2024, 2026, 2028 in the series of baffles 2020, 2022, 2024, 2026, 2028 comprises a base and a tail 2038 extending in a generally upward direction from the base. Moreover, in this aspect a portion of the drilling fluid outlet 2010 within the interior of the gas extraction device 2000 is removed to promote flow of the drilling fluid out of the gas extraction device 2000 via the drilling fluid outlet 2010.

Referring now to FIG. 21 through FIG. 25, a gas extraction device is shown and is generally designated 2100. As illustrated the gas extraction device 2100 can include a generally cylindrical housing 2102 having a top end 2104 and a bottom end 2106. The top end 2104 of the housing 2102 can include a drilling fluid inlet 2108 that can be coupled to a bypass valve, described above, and the bottom end 2106 of the housing 2102 can include a drilling fluid outlet 2110 that can be coupled to a catch reservoir, described above. The top end 2104 of the housing 2102 can also include a gas outlet 2112 that can be connected to the test system, described above. Any gas that is liberated, or extracted, from the drilling fluid (not shown) as it passes through the gas extraction device 2100 can exit the gas extraction device 2100 and can be pumped to the test system by the gas pump, described above.

FIG. 25 indicates that the housing 2102 of the gas extraction device 2100 can include an outer wall 2116 and a plurality of drilling fluid disrupters 2118 can extend from the outer wall 2116 of the housing 2102 of the gas extraction device 2100 in a generally inward and a generally downward direction. Specifically, the plurality of drilling fluid disrupters 2118 can include a first baffle 2120, a second baffle 2122, a third baffle 2124, a fourth baffle 2126, and a fifth baffle 2128. Moving from the top 2104 of the housing 2102 of the gas extraction device 2100 to the bottom 2106 of the housing 2102 of the gas extraction device 2100, the first baffle 2120 is closest to the drilling fluid inlet 2108. The second baffle 2122 is below the first baffle 2120. The third baffle 2124 is below the second baffle 2122. The fourth baffle 2126 is below the third baffle 2124. The fifth baffle 2128 is below the fourth baffle 2126. In a particular aspect, each baffle 2120, 2122, 2124, 2126, 2128 can be a rectangular plate installed at an angle within the gas extraction device 2100.

In a particular aspect, the first baffle 2120, the second baffle 2122, the third baffle 2124, the fourth baffle 2126, and the fifth baffle 2128 can form an angle, α, with respect to a horizontal axis 2129 that is perpendicular to a longitudinal axis 2131 of the housing 2102 of the gas extraction device 2100. As indicated in FIG. 25, α can be the same for each of the baffles 2120, 2122, 2124, 2126, 2128. In one aspect, α can be greater than or equal to 5°. Further, α can be greater than or equal to 7.5°, such as greater than or equal to 10°, greater than or equal to 12.5°, or greater than or equal to 15°. Still in another aspect, α can be less than or equal to 30°, such as less than or equal to 217.5°, less than or equal to 215°, less than or equal to 212.5°, less than or equal to 210°, or less than or equal to 17.5°. It is to be understood that a can be within a range between, and including, any of the values of α described herein.

As illustrated in FIG. 25, each of the baffles 2120, 2122, 2124, 2126, 2128 can include a generally flat base 2130 having a proximal end 2132 extending from, and adjacent to, the sidewall 2116 of the housing 2102 of the gas extraction device 2100 and a distal end 2134 that extends into the interior space 2136 bound by the sidewall 2116 of the housing 2102. Further, each of the baffles 2120, 2122, 2124, 2126, 2128 can include a support structure 2137 that can extend from the sidewall 2116 of the housing 2102 to the distal end 2134 of the base 2130 of each baffle 2120, 2122, 2124, 2126, 2128. The support structure 2137 can provide support for the base 2130 of each baffle 2120, 2122, 2124, 2126, 2128 in order to prevent, or substantially minimize, the base 2130 of each baffle 2120, 2122, 2124, 2126, 2128 from flexing or bending under the weight of the drilling fluid as it passes through the gas extraction device 2100 along the fluid path established between the drilling fluid inlet 2108 and the drilling fluid outlet 2110.

The distal end 2134 of each baffle 2120, 2122, 2124, 2126, 2128 can include a tail 2138 that extends from the base 2130. In one aspect, as illustrated in FIG. 25, each tail 2138 can extend in a generally upward from the distal end 2134 of the base 2130 of each baffle 2120, 2122, 2124, 2126, 2128 and can be substantially parallel to the longitudinal axis 2137 of the gas extraction device 2100. As shown in FIG. 25, each tail 2138 can be straight and each tail can include a height, HT, measured from the lowermost portion of the tail 2138 to the uppermost portion of the tail 2138. In the aspect shown in FIG. 25, HT is the same for the tail 2138 of each baffle 2120, 2122, 2124, 2126, 2128. For example, HT can be than or equal to 5 inches. Further, HT can be less than or equal to 4.5 inches, such as less than or equal to 4.0 inches, less than or equal to 3.5 inches, less than or equal to 3.0 inches, or less than or equal to 21.5 inches. In another aspect, HT is greater than or equal to 0.5 inches, such as greater than or equal to 0.75 inches, greater than or equal to 1.0 inches, greater than or equal to 1.5 inches, or greater than or equal to 21.0 inches. It is to be understood that HT can be within a range between and including any of the values of HT described herein.

FIG. 25 shows that the gas extraction device 2100 can also include a splash plate 2140 adjacent to, or closest to, the drilling fluid outlet 2110. The splash plate 2140 is between the fifth baffle 2128 and the drilling fluid outlet 2110 and helps guide the drilling fluid to the drilling fluid outlet 2110. In particular, the splash plate 2140 can include a generally flat base plate 2142 that can include proximal end 2144 extending from, and adjacent to, the sidewall 2116 of the housing 2102 of the gas extraction device 2100. Further, the generally flat base plate 2142 of the splash plate 2140 can include a distal end 2146 that extends into the interior space 2136 of the housing 2102 of the gas extraction device 2100. FIG. 25 further shows that the splash plate 2140 can include a tail 2148 that extends in a generally downward direction from the distal end 2146 of the base plate 2142 of the splash plate 2140. Further, the splash plate 2140 can also include a central support structure 2150 that can be part of the drilling fluid outlet 2110. As illustrated, an S-trap 2152 can be established between the tail 2148 of the splash plate 2140 and the central support structure 2150 of the splash plate 2140 adjacent to the drilling fluid outlet 2110. The S-trap 2152 can substantially prevent, or minimize, any gases liberated, or extracted, from the drilling fluid from exiting the gas extraction device 2100 via the drilling fluid outlet 2110.

Still referring to FIG. 25, the gas extraction device 2100 can include an impeller 2160 placed in the fluid path between the drilling fluid inlet 2108 and the drilling fluid outlet 2110. The impeller 2160 can include a paddle wheel 2162 and can include a central hub 2164 installed on a pump drive shaft 2166. The pump drive shaft 2166 can be coupled to a gas pump (not shown in FIG. 25). As shown, a plurality of paddles 2168 can extend from the central hub 2164 of the paddle wheel 2162. During operation of the gas extraction device 2100, as the drilling fluid flows through the gas extraction device 2100 along the fluid path between the drilling fluid inlet 2108 and the drilling fluid outlet 2110, the drilling fluid can act on the paddles of the paddle wheel 2162 and can cause the paddle wheel 2162 to rotate. As the paddle wheel 2162 rotates, the pump drive shaft 2166 can rotate and can drive the gas pump connected thereto in order to pump gas out of, and away from, the gas extraction device 2100 where the gas can be collected for analysis and speciation.

In a particular aspect, the housing 2102 of the gas extraction device 2100 can have an overall height, HO, measured from a top of the housing 2102 to a bottom of the housing 2102 and HO can be less than or equal to 5 feet. Further, HO can be less than or equal to 4.5 feet, such as less than or equal to 4.0 feet, less than or equal to 3.5 feet, or less than or equal to 3.0 feet. In another aspect, HO can be greater than or equal to 1.5 feet, such as greater than or equal to 2.0 feet, or greater than or equal to 2.5 feet. It is to be understood that HO can be within a range between, and including, any of maximum and minimum values of HO described herein.

In another aspect, the housing 2102 of the gas extraction device 2100 can have an overall width, WO, as measured from side-to-side, and WO can be less than or equal to 3.0 feet. Moreover, WO can be less than or equal to 2.5 feet, such as less than or equal to 2.0 feet, or less than or equal to 1.5 feet. In another aspect, WO can be greater than or equal to 0.5 feet, such as greater than or equal to 1.0 feet, or greater than or equal to 1.25 feet. It is to be understood that WO can be within a range between, and including, any of the maximum and minimum values of WO described herein.

In another aspect, the housing 2002 of the gas extraction device 2000 can have an internal volume that is less than or equal to 15.0 cubic feet. Further, the internal volume of the housing 2002 can be less than or equal to 12.5 cubic feet, such as less than or equal to 10.0 cubic feet, or less than or equal to 7.5 cubic feet. In still another aspect, the internal volume of the housing 2002 can be greater than or equal to 2.0 cubic feet, such as greater than or equal to 3.0 cubic feet, greater than or equal to 4.0 cubic feet, greater than or equal to 5.0 cubic feet, or greater than or equal to 6.0 cubic feet. It is to be understood that the internal volume of the housing 2002 can be within a range between, and including, any of the maximum and minimum values of the internal volume described herein.

Referring now to FIG. 26, a method of extracting gas from a drilling fluid, e.g., a used drilling fluid, is illustrated and commences at step 2602. Beginning at step 2602, a do loop is entered in which during a drilling operation, one or more of the following steps of the method 2600 can be performed. The various steps of the method 2600 can be performed in the order as illustrated in FIG. 26. However, it may be possible to perform the steps of the method 2600 in a different order. Further, one or more of the steps of the method 2600 may be omitted.

Proceeding to step 3504, the method 2600 can include providing a drilling fluid to a drill bit via an in-line. At step 2606, the method 2600 can include retrieving a used drilling fluid from the drill bit via a return line. It can be appreciated that the drilling fluid can be provided to the drill bit and retrieved from the drill bit via a drilling fluid pump.

Continuing to step 2608, the method 2600 can including determining whether testing is required. If testing is required, the method 2600 can proceed to step 2610. At step 2610, the method 2600 can include bypassing a portion of the used drilling fluid from the return line to a gas extraction device. It is to be understood that the used drilling fluid can be bypassed to the gas extraction device via a bypass valve that can be selectively opened or closed. The bypass valve can be selectively opened when testing is required and selectively closed when no further testing is required.

Moving to step 2612, the method 2600 can include tumbling the used drilling fluid within the gas extraction device to release entrapped gas from the used drilling fluid. At step 2614, the method 2600 can include transmitting the entrapped gas to a test station for analysis and speciation. Further, at step 2616, the method 2600 can include collecting the gas from the used drilling fluid. Thereafter, at step 2618, the method 2600 can include performing analysis and speciation on the gas retrieved from the used drilling fluid.

At step 2620, the method 2600 can include providing the results of the analysis and speciation to an operator. Then, the method 2600 can proceed to step 2622, wherein the method 2600 can include determine whether the drilling operation is complete. If the drilling operation is not complete, the method 2600 can return to step 2604 and the method 2600 can continue as described herein. On the other hand, at step 2622, if the drilling operation is complete, the method 2600 can proceed to step 2624 and the method 2600 can end. Returning to step 2608, if it is determined that testing is not required, the method 2600 can proceed directly to step 2622 and the method 2600 can continue as described herein.

In each of the gas extraction devices described herein, the gas extraction device includes a housing having a drilling fluid inlet and a drilling fluid outlet. A drilling fluid path can be established within the housing and can extend between the drilling fluid inlet to the drilling fluid outlet. Moreover, a plurality of drilling fluid disruptors, e.g., baffles, can be installed along the drilling fluid path. As described herein, the drilling fluid disruptors liberate entrapped gas in the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

The plurality of drilling fluid disruptors can extend inwardly from the exterior wall and the drilling fluid disruptors cause the drilling fluid to tumble within the canister to release entrapped gas from the drilling fluid as the drilling fluid moves along a drilling fluid path within the housing. The drilling fluid disruptors can extract entrapped gas from the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

It is to be understood that in the various embodiments described herein, the angles of the baffles, the shape of the baffles, the tails of the baffles, the surface features extending from the baffles, or a combination thereof can cause the drilling fluid to tumble within the gas extraction device and release gas from the drilling fluid. The gas released, liberated, or extracted from the drilling fluid can be pumped out of the gas extraction device and collected for analysis and speciation. It is also to be understood that other than the impeller, the gas extraction device does not include any moving parts. The drilling fluid disruptors, i.e., the baffles, are stationary, but they impart movement, e.g., tumbling, to the drilling fluid as it passes through the gas extraction device. Further, the baffles are designed to promote laminar flow of the drilling fluid as it enters the gas extraction device via the drilling fluid inlet and then, promote turbulent flow as the drilling fluid flows further down through the gas extraction device.

The various embodiments described herein may be used to extract gas samples when the drilling fluid flow is below an optimized level or above an optimized level. The gas extraction devices described herein can be used to separate relatively small volumes of drilling fluid from which gas can be extracted for analysis and speciation. Moreover, by bypassing drilling fluid from the return line to the gas extraction device, the gas extraction device provides a much safer way to obtain gas samples from the drilling fluid when compared to other ways for obtaining gas samples from drilling fluids and substantially minimizes the risk of injury to those tasked with obtaining the gas samples.

Many different aspects and embodiments are possible. Some of those aspects and embodiments are described herein. After reading this specification, skilled artisans will appreciate that those aspects and embodiments are only illustrative and do not limit the scope of the present invention. Embodiments may be in accordance with any one or more of the items as listed below.

EMBODIMENTS

Embodiment 1. A device for extracting gas from a drilling fluid, the canister comprising:

a housing having a drilling fluid inlet and a drilling fluid outlet;

a drilling fluid path extending between the drilling fluid inlet to the drilling fluid outlet; and

a plurality of drilling fluid disruptors installed along the drilling fluid path, wherein the drilling fluid disruptors liberate entrapped gas in the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

Embodiment 2. A device for extracting gas from a drilling fluid, the canister comprising:

a housing having an exterior wall;

a plurality of drilling fluid disruptors extending inwardly from the exterior wall, wherein the drilling fluid disruptors cause the drilling fluid to tumble within the canister to release entrapped gas from the drilling fluid as the drilling fluid moves along a drilling fluid path within the housing.

Embodiment 3. A device for extracting gas from a drilling fluid, the canister comprising:

a housing;

a drilling fluid path established within the housing; and

a plurality of drilling fluid disruptors installed along the drilling fluid path, wherein the drilling fluid disruptors extract entrapped gas from the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

Embodiment 4. A system for conducing subterranean drilling operations, the system comprising:

at least one drill having a drill string and a drill bit;

at least one pump for proving a drilling fluid to the drill string and the drill bit, the pump having an in line and a return line;

a bypass valve installed along the return line; and

a gas extraction device connected to the bypass valve, wherein the bypass valve can be selectively opened to provide drilling fluid to the gas extraction device, wherein the gas extraction device tumbles drilling fluid within a housing of the gas extraction device to extract entrapped gas from the drilling fluid and wherein the housing of the gas extraction device has an internal volume that is less than or equal to 15 cubic feet.

Embodiment 5. A method of extracting gas from a drilling fluid, the method comprising:

bypassing a portion of a drilling fluid from a return line to a gas extraction device;

tumbling the drilling fluid within the gas extraction device to release entrapped gas from the drilling fluid; and

transmitting the entrapped gas to a test station for analysis.

Embodiment 6. The device according to any of embodiments 1, 2, and 3, wherein the drilling fluid disrupters comprises a series of baffles that extend inwardly from the exterior wall of the housing in alternating directions.

Embodiment 7. The device of embodiment 6, wherein each baffle extends at an angle, α, with respect to a horizontal axis and α is the same for each baffle.

Embodiment 8. The device of embodiment 7, wherein α is greater than or equal to 5°.

Embodiment 9. The device of embodiment 8, wherein α is greater than or equal to 7.5°, such as greater than or equal to 10°, greater than or equal to 12.5°, or greater than or equal to 15°.

Embodiment 10. The device of embodiment 9, wherein α is less than or equal to 30°, such as less than or equal to 27.5°, less than or equal to 25°, less than or equal to 22.5°, less than or equal to 20°, or less than or equal to 17.5°.

Embodiment 11. The device of embodiment 6, wherein each baffle extends at an angle, a, with respect to a horizontal axis and α is different for each baffle.

Embodiment 12. The device of embodiment 11, wherein α increases from an uppermost baffle to a lowermost baffle.

Embodiment 13. The device of embodiment 12, wherein an increase in α is greater than or equal to 1.0°.

Embodiment 14. The device of embodiment 13, wherein the increase in α is greater than or equal to 1.5°, such as greater than or equal to 2.0°, or greater than or equal to 2.5°.

Embodiment 15. The device of embodiment 13, wherein the increase in α is less than or equal to 10°, such as less than or equal to 7.5°, or less than or equal to 5.0°.

Embodiment 16. The device of embodiment 6, wherein each baffle includes a tail that extends in an upward direction from an end of the baffle.

Embodiment 17. The device of embodiment 16, wherein each tail is straight.

Embodiment 18. The device of embodiment 16, wherein each tail is curved.

Embodiment 19. The device of embodiment 18, wherein each tail is curved away from the baffle.

Embodiment 20. The device of embodiment 18, wherein each tail is curved toward the baffle.

Embodiment 21. The device of embodiment 16, wherein alternating tails curve away from the baffle and toward the baffle.

Embodiment 22. The device of embodiment 16, wherein each tail includes a height, HT, measured from the lowermost portion of the tail to the uppermost portion of the tail and HT is the same for the tail of each baffle.

Embodiment 23. The device of embodiment 22, wherein HT less than or equal to 5 inches.

Embodiment 24. The device of embodiment 23, wherein HT is less than or equal to 4.5 inches, such as less than or equal to 4.0 inches, less than or equal to 3.5 inches, less than or equal to 3.0 inches, or less than or equal to 2.5 inches.

Embodiment 25. The device of embodiment 24, wherein HT is greater than or equal to 0.5 inches, such as greater than or equal to 0.75 inches, greater than or equal to 1.0 inches, greater than or equal to 1.5 inches, or greater than or equal to 2.0 inches.

Embodiment 26. The device of embodiment 16, wherein each tail includes a height, HT, measured from the lowermost portion of the tail to the uppermost portion of the tail and HT is different for the tail of each baffle.

Embodiment 27. The device of embodiment 26, wherein HT decreases from an uppermost baffle to a lowermost baffle.

Embodiment 28. The device of embodiment 27, wherein the decrease in HT is greater than or equal to 0.5 inches.

Embodiment 29. The device of embodiment 28, wherein the decrease in HT is greater than or equal to 0.75 inches, such as greater than or equal to 1.0 inches, greater than or equal to 1.25 inches, or greater than or equal to 1.5 inches.

Embodiment 30. The device of embodiment 29, wherein the decrease in HT is less than or equal to 2.5 inches, such as less than or equal to 2.25 inches, less than or equal to 2.0 inches, or less than or equal to 1.75 inches.

Embodiment 31. The device of embodiment 6, wherein each baffle includes a support plate that extends inwardly from the exterior wall of the housing and each support plate is substantially perpendicular to a longitudinal axis of the device.

Embodiment 32. The device according to any of embodiments 1, 2, and 3, wherein the device has an overall height, HO, measured from a top of the housing to a bottom of the housing and HO is less than or equal to 5 feet.

Embodiment 33. The device of embodiment 32, wherein HO is less than or equal to 4.5 feet, such as less than or equal to 4.0 feet, less than or equal to 3.5 feet, or less than or equal to 3.0 feet.

Embodiment 34. The device of embodiment 33, wherein HO is greater than or equal to 1.5 feet, such as greater than or equal to 2.0 feet, or greater than or equal to 2.5 feet.

Embodiment 35. The device according to any of embodiments 1, 2, and 3, wherein the device has an overall diameter, DO, and DO is less than or equal to 3.0 feet.

Embodiment 36. The device of embodiment 35, wherein DO is less than or equal to 2.5 feet, such as less than or equal to 2.0 feet, or less than or equal to 1.5 feet.

Embodiment 37. The device of embodiment 36, wherein DO is greater than or equal to 0.5 feet, such as greater than or equal to 1.0 feet, or greater than or equal to 1.25 feet.

Embodiment 38. The device of embodiment 6, wherein each baffle further comprises at least one surface feature to promote tumbling of the drilling fluid within the device as the drilling fluid flows over each baffle and surface feature.

Embodiment 39. The device of embodiment 38, wherein the at least one surface feature comprises a rib extending in a generally upward direction from the baffle.

Embodiment 40. The device of embodiment 39, wherein the rib comprises a semi-circular cross section.

Embodiment 41. The device of embodiment 40, wherein the rib comprises a triangular cross section.

Embodiment 42. The device according to any of embodiments 1, 2, and 3, further comprising an impellor located along the drilling fluid path within the housing.

Embodiment 43. The device of embodiment 42, wherein the impellor is a paddle wheel.

Embodiment 44. The device of embodiment 43, wherein the paddle wheel is coupled to a shaft on a pump.

Embodiment 45. The device according to any of embodiments 1, 2, and 3, wherein laminar flow of the drilling fluid is promoted on entry into the housing.

Embodiment 46. The device according to any of embodiments 1, 2, and 3, wherein turbulent flow of the drilling fluid is promoted prior to exiting the housing.

Embodiment 47. The device according to any of embodiments 1, 2, and 3, wherein the housing comprises an internal volume that is less than or equal to 15.0 cubic feet.

Embodiment 48. The device of embodiment 47, wherein the internal volume of the housing is less than or equal to 12.5 cubic feet, such as less than or equal to 10.0 cubic feet, or less than or equal to 7.5 cubic feet.

Embodiment 49. The device of embodiment 48, wherein the internal volume of the housing is greater than or equal to 2.0 cubic feet, such as greater than or equal to 3.0 cubic feet, greater than or equal to 4.0 cubic feet, greater than or equal to 5.0 cubic feet, or greater than or equal to 6.0 cubic feet.

Embodiment 50. The device according to any of embodiments 1, 2, and 3, wherein the drilling fluid disruptor comprises a series of baffles and each baffle comprises a base and a tail extending in a generally upward direction from the base.

Embodiment 51. The device of embodiment 50, wherein the tail of each baffle forms an acute angle with respect to the base.

Embodiment 52. The device of embodiment 50, wherein the tail of each baffle forms a right angle with respect to the base.

Embodiment 53. The device of embodiment 50, wherein the tail of each baffle forms an obtuse angle with respect to the base.

Embodiment 54. The device of embodiment 50, wherein the tail of an uppermost baffle forms an acute angle with respect to the base and the tails of the remaining baffles form right angles with respect to the bases.

Embodiment 55. The device of embodiment 50, wherein the tail of an uppermost baffle forms a right angle with respect to the base and the tails of the remaining baffles form acute angles with respect to the bases.

Embodiment 56. The device of embodiment 50, wherein the tail of an uppermost baffle forms an acute angle with respect to the base and the tails of the remaining baffles form obtuse angles with respect to the bases.

Embodiment 57. The device of embodiment 50, wherein the tail of an uppermost baffle forms a right angle with respect to the base and the tails of the remaining baffles form obtuse angles with respect to the bases.

Embodiment 58. The device of embodiment 50, wherein the tail of each baffle is curved.

Embodiment 59. The device of embodiment 58, wherein the tail of each baffle curves away from the base.

Embodiment 60. The device of embodiment 58, wherein the tail of each baffle curves toward from the base.

Embodiment 61. The device of embodiment 58, wherein the tail of an uppermost baffle curves toward the base and the tails of the remaining baffles curved away from the bases.

Embodiment 62. The device of embodiment 58, wherein the tail of an uppermost baffle curves away from the base and the tails of the remaining baffles curved toward the bases.

Embodiment 63. The system of embodiment 4, wherein the gas extraction device comprises the gas extraction device of embodiment 1, 2, or 3.

Embodiment 64. The method of embodiment 5, wherein the gas extraction device comprises the gas extraction device of embodiment 1, 2, or 3.

Embodiment 65. The device according to any of embodiments 1, 2, and 3, wherein the drilling fluid disruptor comprises a series of baffles, a first baffle in the series of baffles comprises a base having an unencumbered distal end and each subsequent baffle in the series of baffles comprises a base and a tail extending in a generally upward direction from the base.

Embodiment 66. The device of embodiment 1, wherein a portion of the drilling fluid outlet within the interior of the gas extraction device is removed to promote flow of the drilling fluid out of the gas extraction device via the drilling fluid outlet.

The specification and illustrations of the embodiments described herein are intended to provide a general understanding of the structure of the various embodiments. The specification and illustrations are not intended to serve as an exhaustive and comprehensive description of all of the elements and features of apparatus and systems that use the structures or methods described herein. Separate embodiments may also be provided in combination in a single embodiment, and conversely, various features that are, for brevity, described in the context of a single embodiment, may also be provided separately or in any subcombination. Further, reference to values stated in ranges includes each and every value within that range. Many other embodiments may be apparent to skilled artisans only after reading this specification. Other embodiments may be used and derived from the disclosure, such that a structural substitution, logical substitution, or another change may be made without departing from the scope of the disclosure. Accordingly, the disclosure is to be regarded as illustrative rather than restrictive. Benefits, other advantages, and solutions to problems have been described above with regard to specific embodiments. However, the benefits, advantages, solutions to problems, and any feature(s) that may cause any benefit, advantage, or solution to occur or become more pronounced are not to be construed as a critical, required, or essential feature of any or all the claims.

The description in combination with the figures is provided to assist in understanding the teachings disclosed herein. The following discussion will focus on specific implementations and embodiments of the teachings. This focus is provided to assist in describing the teachings and should not be interpreted as a limitation on the scope or applicability of the teachings. However, other teachings can certainly be used in this application.

As used herein, the terms “comprises,” “comprising,” “includes,” “including,” “has,” “having” or any other variation thereof, are intended to cover a non-exclusive inclusion. For example, a method, article, or apparatus that comprises a list of features is not necessarily limited only to those features but may include other features not expressly listed or inherent to such method, article, or apparatus. Further, unless expressly stated to the contrary, “or” refers to an inclusive-or and not to an exclusive-or. For example, a condition A or B is satisfied by any one of the following: A is true (or present) and B is false (or not present), A is false (or not present) and B is true (or present), and both A and B are true (or present).

Also, the use of “a” or “an” is employed to describe elements and components described herein. This is done merely for convenience and to give a general sense of the scope of the invention. This description should be read to include one or at least one and the singular also includes the plural, or vice versa, unless it is clear that it is meant otherwise. For example, when a single item is described herein, more than one item may be used in place of a single item. Similarly, where more than one item is described herein, a single item may be substituted for that more than one item.

Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs. The materials, methods, and examples are illustrative only and not intended to be limiting. To the extent not described herein, many details regarding specific materials and processing acts are conventional and may be found in reference books and other sources within the structural arts and corresponding manufacturing arts.

The above-disclosed subject matter is to be considered illustrative, and not restrictive, and the appended claims are intended to cover all such modifications, enhancements, and other embodiments, which fall within the true scope of the present invention. Thus, to the maximum extent allowed by law, the scope of the present invention is to be determined by the broadest permissible interpretation of the following claims and their equivalents, and shall not be restricted or limited by the foregoing detailed description.

Claims

1. A device for extracting gas from a drilling fluid, the device comprising:

a housing having an exterior wall;
a housing having a drilling fluid inlet and a drilling fluid outlet;
a drilling fluid path extending between the drilling fluid inlet to the drilling fluid outlet; and
a plurality of drilling fluid disruptors installed along the drilling fluid path, wherein the drilling fluid disruptors liberate entrapped gas in the drilling fluid as the drilling fluid flows across the drilling fluid disruptors.

2. The device of claim 1, wherein the plurality of drilling fluid disruptors extend inwardly from the exterior wall, and wherein the drilling fluid disruptors cause the drilling fluid to tumble within the housing to release the entrapped gas from the drilling fluid as the drilling fluid moves along the drilling fluid path within the housing.

3. The device of claim 1, wherein the drilling fluid disrupters comprise a series of baffles that extend inwardly from the exterior wall of the housing in alternating directions.

4. The device of claim 3, wherein each baffle extends at an angle, α, with respect to a horizontal axis of the device and α is the same for each baffle.

5. The device of claim 4, wherein α is greater than or equal to 5°, and wherein α is less than or equal to 30°.

6. The device of claim 3, wherein each baffle extends at an angle, α, with respect to a horizontal axis of the device and α is different for each baffle.

7. The device of claim 6, wherein α increases from an uppermost baffle to a lowermost baffle.

8. The device of claim 7, wherein an increase in a between adjacent ones of the baffles is greater than or equal to 1.0°.

9. The device of claim 3, wherein each baffle includes a tail that extends in an upward direction from an end of the baffle.

10. The device of claim 9, wherein each tail includes a height, HT, measured from the lowermost portion of the tail to the uppermost portion of the tail.

11. The device of claim 10, wherein HT is the same for the tail of each baffle, and wherein HT is less than or equal to 5 inches.

12. The device of claim 10, wherein HT is different for the tail of each baffle, and wherein HT decreases from an uppermost baffle to a lowermost baffle.

13. The device of claim 1, wherein the device has an overall height, HO, measured from a top of the housing to a bottom of the housing and HO is less than or equal to 5 feet, and wherein the device has an overall diameter, DO, and DO is less than or equal to 3.0 feet.

14. The device of claim 1, wherein each baffle further comprises at least one surface feature to promote tumbling of the drilling fluid within the device as the drilling fluid flows over each baffle and surface feature.

15. The device of claim 1, further comprising an impellor located along the drilling fluid path within the housing, wherein the impellor configured to rotate as fluid engages the impellor, and wherein rotation of the impellor drives a generator that generates electricity.

16. The device of claim 1, wherein the housing comprises an internal volume that is less than or equal to 15.0 cubic feet.

17. A system for conducing subterranean drilling operations, the system comprising:

at least one drill having a drill string and a drill bit;
at least one pump for providing a drilling fluid to the drill string and the drill bit, the pump having an in-line and a return line;
a bypass valve installed along the return line; and
a gas extraction device connected to the bypass valve, wherein the bypass valve can be selectively opened to provide drilling fluid to the gas extraction device, wherein the gas extraction device tumbles drilling fluid within a housing of the gas extraction device to extract entrapped gas from the drilling fluid.

18. The system of claim 17, wherein the housing has a fluid inlet and a fluid outlet, and wherein the gas extraction device further comprises:

a fluid path extending between the fluid inlet to the fluid outlet; and
a plurality of fluid disruptors installed along the fluid path, wherein the fluid disruptors liberate entrapped gas in the drilling fluid as the drilling fluid flows across the fluid disruptors.

19. A method of extracting gas from a drilling fluid, the method comprising:

bypassing a portion of a drilling fluid from a return line to a gas extraction device;
tumbling the drilling fluid within the gas extraction device to release entrapped gas from the drilling fluid; and
transmitting the entrapped gas to a test station for analysis.

20. The method of claim 19, wherein the gas extraction device comprises:

a housing having an exterior wall; and
a plurality of drilling fluid disruptors extending inwardly from the exterior wall, wherein the drilling fluid disruptors cause the drilling fluid to tumble within the housing to release entrapped gas from the drilling fluid as the drilling fluid moves along a drilling fluid path within the housing.
Patent History
Publication number: 20200400018
Type: Application
Filed: Jun 18, 2020
Publication Date: Dec 24, 2020
Inventors: Albert NEUBERT (Bakersfield, CA), Jeremy WHITT (Spring, TX)
Application Number: 16/905,444
Classifications
International Classification: E21B 49/08 (20060101); E21B 21/06 (20060101); E21B 49/00 (20060101);