US20050028974A1

US20050028974A1 - Apparatus for obtaining high quality formation fluid samples

Info

Publication number: US20050028974A1
Application number: US10/911,357
Authority: US
Inventors: Michael Moody
Original assignee: PathFinder Energy Services Inc
Current assignee: PathFinder Energy Services Inc
Priority date: 2003-08-04
Filing date: 2004-08-04
Publication date: 2005-02-10
Also published as: CA2476532A1; GB2405652B; GB2405652A; GB0417432D0

Abstract

A well fluid sampling tool is provided. The sampling tool includes at least one insulated sample chamber mounted in a tool collar. The tool collar may be coupled with a drill string such that, when the tool collar is deployed in a well bore, selected sample chambers may receive a fluid sample from outside the drill string without removing the drill string from the well bore (e.g., during measurement while drilling or logging while drilling operations). A heating module in thermal communication with at least one of the sample chambers is disposed to selectively heat the sample chambers in thermal communication therewith. The sampling tool may be particularly useful for acquiring and preserving substantially pristine formation fluid samples.

Description

RELATED APPLICATIONS

This application claims the benefit of U.S. Provisional Application Ser. No. 60/492,483 entitled Apparatus for Obtaining High Quality Formation Fluid Samples, filed Aug. 4, 2003.

FIELD OF THE INVENTION

The present invention relates generally to the drilling of oil and gas wells, and more specifically, to a formation fluid sampling tool and method of use for acquiring and preserving substantially pristine formation fluid samples.

BACKGROUND OF THE INVENTION

The commercial development of hydrocarbon (e.g., oil and natural gas) fields requires significant capital investment. Thus it is generally desirable to have as much information as possible pertaining to the contents of a hydrocarbon reservoir and/or geological formation in order to determine its commercial viability. There have been significant advances in measurement while drilling and logging while drilling technology in recent years (hereafter referred to as MWD and LWD, respectively). These advances have improved the quality of data received from downhole sensors regarding subsurface formations. It is nonetheless still desirable to obtain one or more formation fluid samples during the drilling and completion of an oil and/or gas well. Once retrieved at the surface, these samples typically undergo specialized chemical and physical analysis to determine the type and quality of the hydrocarbons contained therein. In general, it is desirable to collect the samples as early as possible in the life of the well to minimize contamination of the native hydrocarbons by drilling damage.
As is well known to those of ordinary skill in the art, formation fluids (e.g., water, oil, and gas) are found in geological formations at relatively high temperatures and pressures (as compared to ambient conditions at the surface). At these relatively high temperatures and pressures, the formation fluid is typically a single-phase fluid, with the gaseous components being dissolved in the liquid. A reduction in pressure (such as may occur by exposing the formation fluid to ambient conditions at the surface) typically results in the separation of the gaseous and liquid components. Cooling of the formation fluid towards such ambient temperatures typically results in a reduction in volume (and therefore a reduction in pressure if the fluid is housed in a sealed container), which also tends to result in a separation of the gaseous and liquid components. Cooling of the formation fluid may also result in substantially irreversible precipitation and/or separation of other compounds previously dissolved therein. Thus it is generally desirable for a sampling apparatus to be capable of substantially preserving the temperature and/or pressure of the formation fluid in its primitive formation condition.
Berger et al., in U.S. Pat. No. 5,803,186, disclose an apparatus and method for obtaining samples of formation fluid using a work string designed for performing other downhole work such as drilling, workover operations, or re-entry operations. The apparatus includes sensors for sensing downhole conditions while using a work string that permits working fluid properties to be adjusted without withdrawing the work string from the well bore. The apparatus also includes a relatively small integral sample chamber coupled to multiple input and output valves for collecting and housing a formation fluid sample.
Schultz et al., in U.S. Pat. No. 6,236,620, disclose an apparatus and method for drilling, logging, and testing a subsurface formation without removing the drill string from the well bore. The apparatus includes a surge chamber and surge chamber receptacle for use in sampling formation fluids. The surge chamber is lowered through the drill string into engagement with the surge chamber receptacle, receives a sample of formation fluid, and then is retrieved to the surface. Repeated sampling may be accomplished without removing the drill string by removing the surge chamber, evacuating it, and then lowering it back into the well. While the Berger and Schultz apparatuses apparently permit samples to be collected relatively early in the life of a well, without retrieval of the drill string, they include no capability to preserve the temperature of the formation fluid. Further, it is a relatively complex operation to remove the formation fluid sample from the Berger apparatus.
Brown et al., in U.S. Pat. No. 5,901,788 disclose a wire or slick line apparatus in which the sample chamber may be thermally insulated, given a high heat capacity, and/or provided with a heating source such as an electric heater, with the intent of maintaining the sample at a temperature similar to that of the formation. Corrigan et al., in PCT Publication WO 00/34624, disclose a slick line apparatus including a sample chamber contained within an evacuated jacket for maintaining the temperature of a formation fluid sample. The Corrigan apparatus further includes multiple heaters spaced along the sample chamber. One drawback of the Brown and Corrigan apparatuses is that they require the retrieval of the drill string from the well bore prior to being lowered therein, which typically involves significant cost and time, and increases the risk of subsurface damage to the formation of interest.
Therefore, there exists a need for improved apparatuses and methods for obtaining samples of formation fluid from a well. In particular, an apparatus that does not require retrieval of the drill string from the well and that has the capability of preserving the sample of formation fluid in substantially pristine conditions is highly desirable.

SUMMARY OF THE INVENTION

The present invention addresses difficulties in acquiring and preserving samples of pristine formation fluid, including those difficulties described above. Aspects of this invention include a sampling tool for obtaining samples of relatively pristine formation fluid without removing the drill string from the well bore. Sampling tools according to the invention may retrieve samples from both deep and shallow wells. Exemplary sampling tool embodiments of this invention are configured for coupling to the drill string and include one or more sample chambers. The sample chambers are typically insulated and/or provided with a heat source (also referred to as a heating module, e.g., an electric heater) for maintaining the temperature of the formation fluid. Sampling tool embodiments according to this invention typically further include on-board electronics disposed to collect multiple samples of pristine formation fluid at substantially any predetermined moment or time interval.
Exemplary embodiments of the present invention may advantageously provide several technical advantages. For example, sampling tool embodiments according to this invention may advantageously provide for improved sampling of formation fluid from, for example, deep wells. In particular, embodiments of this invention are configured with the intent to try to maintain, for as long as possible, the fluid at about the same temperature and pressure conditions as found in the formation. A tool according to this invention, in combination with a logging while drilling (LWD) tool, is couplable to a drill string, and thus in such a configuration provides for sampling of formation fluid shortly after penetration of the formation of interest. Advantages are thus provided for the acquisition and preservation of relatively high quality formation fluid sample in substantially pristine conditions. These high quality samples may provide for more accurate determination of formation properties and thus may enable a better assessment of the economic viability of an oil and/or gas reservoir.
In one aspect the present invention includes a downhole sampling tool. The downhole sampling tool includes a tool collar having at least one sample chamber deployed therein. Each sample chamber includes an insulating layer deployed thereabout. The tool collar is disposed to be operatively coupled with a drill string deployed in a well bore such that, when the tool collar is coupled to the drill string, sample chambers may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore. The sampling tool further includes a heating module in thermal communication with at least one of the sample chambers. The heating module is disposed to selectively heat the sample chambers in thermal communication therewith.
In another aspect this invention includes a logging while drilling (LWD) tool. The logging while drilling tool includes a tool collar having at least one chamber mounted therein. Each sample chamber includes an insulating layer deployed thereabout. The tool collar is disposed to be operatively coupled with a drill string deployed in a well bore such that, when the tool collar is coupled to the drill string, sample chambers may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore. The LWD tool further includes a heating module in thermal communication with at least one of the sample chambers. The heating module is disposed to selectively heat the sample chambers in thermal communication therewith. The LWD tool still further includes at least one packer element. Each packer element is disposed to seal the wall of the well bore around the LWD tool. Each packer element is further selectively positionable between sealed and unsealed positions. The LWD yet further includes a sample inlet port connected to the at least one sample chamber via an inlet passageway.
The foregoing has outlined rather broadly the features and technical advantages of the present invention in order that the detailed description of the invention that follows may be better understood. Additional features and advantages of the invention will be described hereinafter, which form the subject of the claims of the invention. It should be appreciated by those skilled in the art that the conception and the specific embodiment disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the present invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present invention, and the advantages thereof, reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:
FIG. 1 is a schematic illustration of an offshore oil and/or gas drilling platform utilizing an exemplary embodiment of the present invention.
FIG. 2 is a partially cutaway schematic representation of an exemplary sampling module embodiment according to the present invention.
FIG. 3 is a partially cutaway schematic representation of an exemplary embodiment of a sample chamber insert for use with the exemplary sampling module of FIG. 2.
FIG. 4 is a partially cutaway schematic representation of an exemplary sampling tool according to the present invention, including the exemplary sampling module of FIG. 2.

DETAILED DESCRIPTION

Referring now to FIG. 1, one exemplary embodiment of sampling module 100 according to this invention is schematically illustrated in use in an offshore oil or gas drilling assembly, generally denoted 10. A semisubmersible drilling platform 12 is positioned over an oil or gas formation 14 disposed below the sea floor 16. A subsea conduit 18 extends from deck 20 of platform 12 to a wellhead installation 22. The platform may include a derrick 26 and a hoisting apparatus 28 for raising and lowering the drill string 30 including drill bit 32, sampling module 100, and formation tester 200. Drill string 30 may further include a downhole drill motor, a mud pulse telemetry system, and one or more sensors, such as a nuclear logging instrument, for sensing downhole characteristics of the well, bit, and reservoir.
During a drilling, testing, and sampling operation, drill bit 32 is rotated on drill string 30 to create a well bore 40. Shortly after the drill bit 32 intersects the formation 14 of interest, drilling typically stops to allow formation testing before contamination of the formation occurs, e.g., by invasion of working fluid or filter cake build-up. Expandable packers 220 are inflated to sealing engage the wall of well bore 40. The inflated packers 220 isolate a portion of the well bore 40 adjacent the formation 14 to be tested. Formation fluid is then received at port 216 of formation tester 200 and may be pumped into one or more sample chambers 122 illustrated on FIG. 2. As described in more detail hereinbelow with respect to FIG. 4, embodiments of formation tester 200 may include a fluid identification module 210 including one or more sensors for sensing properties of the various fluids that may be encountered. Formation tester 200 may further pass fluid through a fluid passageway to one or more sample tanks housed in sample module 100.
It will be understood by those of ordinary skill in the art that the sampling module 100 and the formation tester 200 of the present invention are not limited to use with a semisubmersible platform 12 as illustrated on FIG. 1. Sampling module 100 and formation tester 200 are equally well suited for use with any kind of subterranean drilling operation, either offshore or onshore.
Referring now to FIGS. 2 and 3, a schematic illustration of one exemplary embodiment of the sampling module 100 (also referred to herein as a sampling tool) according to this invention is shown. Sampling module 100 includes one or more sample tanks 120 disposed in a collar 110. Collar 110 is typically configured for mounting on a drill string, e.g., drill string 30 (FIG. 1), and thus may include conventional threaded connectors on the top and bottom thereof. While FIGS. 2 and 3 show a sampling module including three sample tanks 120, the artisan of ordinary skill will readily recognize that sampling module 100 may include substantially any number of sample tanks disposed in substantially any arrangement in the collar 110.
As described hereinabove, sample tanks 120 are configured to maintain the temperature of the formation fluid at a value substantially equal to that of the formation (e.g., formation 14 in FIG. 1). In the embodiment of FIG. 2, sample tanks 120 include a sample chamber 122 surrounded by one or more insulating layers 124. The sample chamber 122 may be fabricated from, for example, stainless steel or a titanium alloy, although it will be appreciated that it may be fabricated from substantially any suitable material in view of the service temperatures and pressures, exposure to corrosive formation fluids, and other downhole conditions. Insulating layer 124 may include substantially any suitable thermally insulating material, such as a polyurethane coating or an aerogel foam disposed on the sample chamber 122. Insulating layer 124 may further include an evacuated annular region, the vacuum around the sample chamber 122 further enhancing the thermal insulation thereof. In one desirable embodiment insulating layer 124 is sufficient to substantially maintain the temperature of a sample at the formation temperature, the sample chamber 124 having an revalue of, for example, greater than or equal to about 12.
With further reference to the embodiment of FIG. 2, the exterior of the sample chamber 122 is wound with an electrical resistance heating module 128 typically in the form of a tape, foil, or chain. Sample chamber 122 may alternately be coated with an electrically resistive coating. The heating module 128 is typically communicably coupled to a controller (shown schematically at 140) mounted inside the collar 110. In embodiments in which the heating module 128 includes an electrical heating mechanism, electric power may be provided by substantially any known electrical system, such as a battery pack mounted in the tool body 110, or elsewhere in the drill string, or a turbine disposed in the flow of drilling fluid. Alternately and/or additionally, the sample chamber may be heated using known chemical techniques, e.g., by a controlled exothermic chemical reaction in a separate chamber (not shown).
Referring again to FIG. 2, the one or more sample chambers 122 are in fluid communication with a sample fluid passageway 130 including an inlet port 134 for receiving formation fluid (e.g. from an LWD tool). Passageway 130 is further in fluid communication with inlet valves 132 for controlling the flow of the formation fluid to the one or more sample chambers 122. Inlet valves 132 are communicably coupled to the controller 140 and allow collection of separate fluid samples in each of the sample chambers 122 (e.g., at unique times or penetration depths). Multiple samples may also be collected simultaneously and optionally held at separate temperatures, thus providing additional information about the temperature and pressure stability of the formation fluid.
With continued reference to FIG. 2, controller 140 may include a programmable processor (not shown), such as a microprocessor or a microcontroller, and may also include processor readable or computer readable program code embodying logic, including instructions for controlling the function of valves 132 and heating modules 128. Controller 140 may be disposed in communication with one or more temperature probes (not shown) appropriately sized, shaped, positioned, and configured for providing temperature readings of the interior of the sample chambers 122. The temperature probes may include, for example a thermistor or a thermocouple in thermal contact with the samples. Controller 140 may optionally be disposed in electronic communication with other sensors and/or probes for monitoring other physical parameters of the samples (e.g., a pressure sensor for measuring the pressure of the interior of the sample chamber 122). Controller 140 may also optionally be disposed in electronic communication with other sensors for measuring well bore properties, such as a gamma ray depth detection sensor or an accelerometer, gyro or magnetometer to detect azimuth and inclination. Controller 140 may also optionally communicate with other instruments in the drill string, such as telemetry systems that communicate with the surface. Controller 140 may further optionally include volatile or non-volatile memory or a data storage device. The artisan of ordinary skill will readily recognize that while controller 140 is shown disposed in collar 110 (FIG. 2), it may alternately be disposed elsewhere, such as in identification module 210 of fluid tester 200.
In alternative embodiments, sampling module 100 may be configured to include a sample chamber insert 150 mountable in the collar 110 as illustrated on FIG. 3. The sample chamber insert 150 may, for example, include the one or more sample tanks 120, the fluid passageway 130, the inlet valves 132, and the controller 140 disposed in a housing 152. This embodiment may be advantageous in that the sample chamber insert 150, including the sample tanks 120, may be removed from the collar 110 and transported to a remote location for sample testing.
Referring now to FIG. 4, another embodiment of the present invention includes a sample module 100 coupled to a formation tester 200 (e.g., a LWD tool). While sample module 100 and formation tester 200 are shown coupled at 235 (e.g., threaded to one another), the artisan of ordinary skill will readily recognize that consistent with the present invention they may also be fabricated as an integral unit. Formation tester 200 may be according to embodiments described and claimed in U.S. Pat. No. 6,236,620 to Schultz, et al. and typically includes one or more packer elements 220 for selectively sealing the wall of the well bore around formation tester 200. FIG. 4 illustrates two packer elements 220 for isolating a substantially annular portion of the well bore adjacent to a formation of interest. The packer elements 220 may comprise any type packer element, such as compression type or inflatable type. Inflatable type packer elements 220 may be inflated by substantially any suitable technique, such as by injecting a pressurized fluid into the packer. The packer elements 220 may further include optional covers (not illustrated on FIG. 4) to shield the components thereof from the potentially damaging effects of the various forces encountered during drilling (e.g., collisions with the wall of the well bore).
With further reference to FIG. 4, the formation tester 200 further includes at least one inlet port 216 disposed between packer elements 220. In embodiments including only one packer element 220, inlet port 216 is typically disposed therebelow (e.g., further towards the bottom of the well). Inlet port 216 is in fluid communication with a fluid identification module (shown schematically at 210) via fluid passageway 218. Fluid identification module 210 typically includes instrumentation including one or more sensors for monitoring and recording properties of the various fluids that may be encountered in the well bore, from which a fluid type may be determined. For example, sensor measurements may distinguish between working fluid (e.g., drilling mud) and formation fluid. The fluid identification module 210 may include any of a relatively wide variety of sensors, including a resistivity sensor for sensing fluid or formation resistivity and a dielectric sensor for sensing the dielectric properties of the fluid or formation. Module 210 may further include pressures sensors, temperature sensors, optical sensors, acoustic sensors, nuclear magnetic resonance sensors, density sensors, viscosity sensors, pH sensors, and the like. Fluid identification module 210 typically further includes numerous valves and fluid passageways (not shown) for directing formation fluid to the various sensors and for directing fluid to, for example, a sample output passageway 214 or a fluid discharge passageway 212, in fluid communication with output port 213.
Formation tester 200 typically further includes a control module (not shown) of analogous purpose to that described above with respect to controller 140. The control module, for example controls the function of the various sensors described above and communicates sensor output with operators at the surface, for example, by conventional mud telemetry or electric line communications techniques. The control module may further be communicably coupleable with controller 140.
In operation, formation tester 200 is advantageously positioned adjacent a formation of interest in the well bore. The packer elements 220 are inflated, thereby isolating a substantially annular portion of the well bore adjacent the formation. One or more pumps 250 are utilized to pump formation fluid into the tool at port 216. The pump 250 may include, for example, a bi-directional piston pump, such as that disclosed in U.S. Pat. Nos. 5,303,775 and 5,377,755 to Michaels et al., or substantially any other suitable pump in view of the service temperatures and pressures, exposure to corrosive formation fluids, and other downhole conditions. Fluid is typically pumped into the tool (rather than flowing by the force of the reservoir pressure) in order to maintain it above its bubble pressure (i.e., the pressure below which a single phase fluid becomes a two phase fluid). Sampled formation fluid then passes through the fluid identification module 210 where it is tested using one or more of the various sensors described above. Fluid is typically pumped in and then discharged from the tool via passageway 212 and output port 213 until it is sensed to have predetermined properties (e.g., a resistivity in a certain range) identifying it as likely to be a substantially pristine formation fluid. Typically, upon first pumping, the formation fluid is contaminated with drilling fluid. After some time, however, substantially pristine formation fluid may be drawn into the tool and routed to sampling module 100 via passageway 214. Samples may be obtained using substantially any protocol (e.g., at a various time intervals or matching certain predetermined fluid properties measured by identification module 210).
Referring now to FIG. 2, with further reference to FIG. 4, substantially pristine formation fluid may be received at inlet port 134, which is in fluid communication with fluid passageway 214, and routed to one or more sample chambers 122 through valves 132. If the sample temperature falls, such a temperature change may be detected by the controller 140, (e.g., using a thermistor or thermocouple in thermal contact with the sample). In response to the detected temperature drop, the control circuit may, for example, connect an electrical power supply (e.g., a battery source) with the electrical heating module 128 to heat the sample chamber 122 and thus stabilize the temperature of the sample.
Although the present invention and its advantages have been described in detail, it should be understood that various changes, substitutions and alternations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.

Claims

1. A downhole sampling tool, comprising:

a tool collar, the tool collar including at least one sample chamber deployed therein, each sample chamber including an insulating layer deployed thereabout;

the tool collar disposed to be operatively coupled with a drill string deployed in a well bore such that, when the tool collar is coupled to the drill string, sample chambers may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore; and

a heating module in thermal communication with at least one of the sample chambers, the heating module disposed to selectively heat said sample chambers in thermal communication therewith.

2. The sampling tool of claim 1, further comprising a sample inlet port on an outer surface of the tool collar, the sample inlet port connected to the sample chamber via a fluid passageway.

3. The sampling tool of claim 2, further comprising a pump in fluid communication with the sample inlet port.

4. The sampling tool of claim 3, wherein the pump comprises a bi-directional piston pump.

5. The sampling tool of claim 1, wherein the tool collar comprises a plurality of sample chambers deployed therein.

6. The sampling tool of claim 1, wherein the at least one sample chamber is deployed substantially coaxially with the tool collar.

7. The sampling tool of claim 1, wherein the insulating layer comprises an r-value of greater than or equal to 12.

8. The sampling tool of claim 1, wherein the insulating layer comprises an insulating material selected from the group consisting of a polyurethane coating and an aerogel foam.

9. The sampling tool of claim 1, wherein the insulating layer comprises an evacuated region.

10. The sampling tool of claim 1, wherein the heating module comprises an electrical resistance heater.

11. The sampling tool of claim 10, wherein a portion of the heating module is wound about the sample chamber.

12. The sampling tool of claim 10, wherein the heating module comprises an electrically resistive coating deployed about the sample chamber.

13. The sampling tool of claim 1, further comprising an electronic controller in control communication with the heating module.

14. The sampling tool of claim 13, wherein the electronic controller is further in control communication with at least one temperature sensor deployed in the sample chamber.

15. The sampling tool of claim 14, wherein the electronic controller is configured to maintain a temperature of the sample chamber above a predetermined minimum temperature.

16. The sampling tool of claim 1, being coupled to a logging while drilling tool.

17. The sampling tool of claim 1, wherein the sample chamber and the heating module are deployed in a sample chamber insert, the sample chamber insert sized and shaped for removable receipt within the tool collar.

18. A downhole sampling tool, comprising:

a tool collar, the tool collar including a sample chamber insert deployed therein, the sample chamber insert sized and shaped for removable receipt within the tool collar;

at least one sample chamber deployed in the sample chamber insert, each sample chamber including an insulating layer deployed thereabout;

a heating module deployed in the sample chamber insert in thermal communication with at least one of the sample chambers, the heating module disposed to selectively heat said sample chambers in thermal communication therewith; and

the tool collar disposed to be operatively coupled with a drill string deployed in a well bore such that, when the tool collar is coupled to the drill string, sample chambers may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore.

19. The sampling tool of claim 18 wherein the insulating layer comprises an insulating material selected from the group consisting of a polyurethane coating and an aerogel foam.

20. The sampling tool of claim 19, wherein the insulating layer comprises an evacuated region.

21. The sampling tool of claim 18, wherein the heating module comprises an electrical resistance heater, a portion of the electrical resistance heater wound about at least one of the sample chambers.

22. The sampling tool of claim 18, further comprising an electronic controller communicably coupled with (i) the heating module and (ii) at least one temperature sensor deployed in the sample chamber.

23. The sampling tool of claim 22, wherein the electronic controller is configured to maintain a temperature of the sample chamber above a predetermined minimum temperature.

24. The sampling tool of claim 18, further comprising a bi-directional piston pump connected to a sample inlet port, the sample inlet port connected to the sample chamber via a fluid passageway.

25. A logging while drilling tool comprising:

a tool collar, the tool collar including at least one sample chamber mounted therein, each sample chamber including an insulating layer deployed thereabout;

the tool collar disposed to be operatively coupled with a drill string deployed in a well bore such that, when the tool collar is coupled to the drill string, sample chambers may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore;

a heating module in thermal communication with at least one of the sample chambers, the heating module disposed to selectively heat said sample chambers in thermal communication therewith;

at least one packer element, each packer element disposed to seal the wall of the well bore around the logging while drilling tool, each packer element being selectively positionable between sealed and unsealed positions; and

a sample inlet port connected to the at least one sample chamber via an inlet passageway.

26. The logging while drilling tool of claim 25, comprising first and second packer elements, the sample inlet port being disposed between the first and second packer elements.

27. The logging while drilling tool of claim 25, further comprising a fluid identification module in fluid communication with the inlet passageway, the fluid identification module including at least one sensor disposed to sense a property of a formation fluid.

28. The logging while drilling tool of claim 27, wherein at least one of the sensors in the fluid identification module is selected from the group consisting of a resistivity sensor, a dielectric sensor, a pressure sensor, a temperature sensor, an optical sensor, an acoustic sensor, a nuclear magnetic resonance sensor, a density sensor, a viscosity sensor, and a pH sensor.

29. The logging while drilling tool of claim 27, further comprising:

a first fluid passageway connecting the fluid identification module to the at least one sample chamber; and

a second fluid passageway connecting the fluid identification module to an output port through which fluid may be expelled from the tool.

30. The logging while drilling tool of claim 25, wherein the tool collar comprises a plurality of sample chambers mounted therein.

31. The logging while drilling tool of claim 25, wherein the insulating layer comprises an r-value of greater than or equal to 12.

32. The logging while drilling tool of claim 25, wherein the heating module comprises an electrical resistance heater wound about the sample chamber.

33. The logging while drilling tool of claim 25, further comprising an electronic controller in control communication with the heating module.

34. The logging while drilling tool of claim 25, further comprising a bi-directional piston pump in fluid communication with the sample inlet port.

35. The logging while drilling tool of claim 25, wherein the sample chamber and the heating module are deployed in a sample chamber insert, the sample chamber insert sized and shaped for removable receipt within the tool collar.

36. An integrated apparatus for retrieving a fluid sample from a well bore, the apparatus comprising:

a drill string having a drill bit disposed on one end thereof;

a formation evaluation tool disposed on the drill string proximate to the drill bit; and

a formation fluid sampling apparatus also disposed on the drill string proximate to the drill bit, the formation fluid sampling apparatus including:

the tool collar disposed to be operatively coupled with the drill string such that sample chambers may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore; and

37. A method for acquiring a formation fluid sample from a formation of interest in a well bore, the method comprising:

(a) deploying a formation fluid sampling tool at a location of a formation of interest in a well bore, the sampling tool being operative coupled with a drill string proximate to a drill bit, the sampling tool comprising:

the tool collar disposed such that the at least one sample chamber may be selectively placed in fluid communication with formation fluid drawn from outside the drill string without removing the drill string from the well bore; and

(b) pumping formation fluid into selected ones of the sample chambers; and

(c) heating the formation fluid received in (b) in the selected sample chambers using the heating module.