Downhole hydrogen sulfide capture and measurement

1. A fluid sampling tool for sampling fluid from a subterranean formation, comprising:

a sample chamber having a fluid inlet, wherein the sample chamber comprises walls lined entirely with a coating of a sorbent material, wherein the sorbent material is a structured or a porous material that increases a surface to volume ratio and consists of gold, nickel, platinum, or combinations thereof;

a channel fluidically coupled to the sample chamber and a pump;

a probe, wherein the probe is extendable to engage the subterranean formation from a wellbore; and

a chamber valve disposed within the channel.

2. The fluid sampling tool of claim 1 , wherein the fluid sampling tool further comprises the pump coupled to the probe for pumping fluid from the subterranean formation, wherein the sample chamber is coupled to the pump for receiving a fluid sample pumped from the subterranean formation through the probe.

3. The fluid sampling tool of claim 1 , further comprising more than one sample chamber.

4. The fluid sampling tool of claim 1 , wherein the sample chamber comprises a sample fluid.

5. The fluid sampling tool of claim 1 , wherein a sample fluid comprises at least one component selected from the group consisting of hydrogen sulfide, mercury, carbon dioxide, and combinations thereof.

6. The fluid sampling tool of claim 1 , wherein the porous or structured pattern material is formed from at least one lithographic technique selected from the group consisting of etching, anodizing, patterning, and combinations thereof.

7. The fluid sampling tool of claim 1 , wherein at least one surface of the fluid sampling tool is coated with a protective coating of aluminum oxide that is resistant to hydrogen sulfide.

8. The fluid sampling tool of claim 1 , wherein the sorbent material is backed with an inert material.

9. The fluid sampling tool of claim 8 , wherein the inert material comprises aluminum oxide, beryllium oxide, or a combination thereof.

10. The fluid sampling tool of claim 1 , further comprising a second valve disposed within the channel, wherein the chamber valve allows a fluid sample to enter the sample chamber and the second valve prevents the fluid sample from directly entering the wellbore.

11. The fluid sampling tool of claim 1 , further comprising more than one probe.

12. A method for sampling formation fluids, comprising:

inserting a sample chamber into a wellbore, wherein the sample chamber comprises walls lined entirely with a coating of a sorbent material, wherein the sorbent material is a structured or a porous material that increases a surface to volume ratio and consist of gold, nickel, platinum, or combinations thereof;

engaging a probe with the borehole wall, wherein the probe extends from the sample chamber;

collecting a fluid sample with the probe; and

placing the fluid sample into the sample chamber while disposed in the wellbore in which the fluid sample is at least partially sorbed by the sorbent material.

13. The method of claim 12 , wherein at least 99% by volume of at least one component from the fluid sample selected from the group consisting of hydrogen sulfide, mercury, carbon dioxide, and combinations thereof is sorbed by the sorbent material.

14. The method of claim 12 , further comprising retrieving the sample chamber from the wellbore, desorbing the fluid sample from the sorbent material, and measuring a quantity of the desorbed formation fluid.

15. The method of claim 14 , wherein the desorbing comprises heating the sample chamber.

16. The method of claim 14 , further comprising:

collecting one or more additional fluid samples in one or more additional sample chambers while disposed in the wellbore, wherein the one or more additional sample chambers are lined with the sorbent material such that at least a portion of the sample fluid present in the one or more additional fluid samples is at least partially sorbed by the sorbent material in the one or more additional sample chambers;

retrieving the one or more additional sample chambers from the wellbore;

desorbing the sample fluid from the sorbent material in the one or more additional samples chambers;

measuring a quantity of the desorbed component from the one or more additional sample chambers; and

extrapolating the quantity of the desorbed component from the one or more additional sample chambers and the desorbed component from the sample chamber to a reservoir concentration.

17. The method of claim 12 , wherein the sample fluid comprises hydrogen sulfide and wherein at least one surface of a fluid sampling tool comprising the sample chamber is partially coated with a protective coating that is resistant to the sample fluid.

18. The method of claim 12 , further comprising:

heating the sample chamber with a heating element;

measuring a desorbed component with a fluid analyzer from the sample chamber;

creating a suction with a vacuum pump to transfer the desorbed component from the sample chamber to the fluid analyzer; and

processing received inputs from the fluid analyzer to determine a concentration of the desorbed component.

19. The method of claim 18 , wherein the fluid analyzer is selected from a mass spectrometer, a gas chromatograph, an optical sensor, and combinations thereof.

20. The method of claim 12 , wherein the sorbent material is backed with an inert material that comprises aluminum oxide, beryllium oxide, or a combination thereof.