DETECTING TRACER BREAKTHROUGH FROM MULTIPLE WELLS COMMINGLED AT A GAS OIL SEPARATION PLANT

Methods and systems for determining tracer breakthrough from multiple wells commingled at a Gas Oil Separation Plant (GOSP) are provided. An example hydrocarbon reservoir monitoring method includes periodically sampling fluid carried by a water line of a Gas Oil Separation Plant (GOSP). The GOSP is configured to receive commingled well hydrocarbon fluids from multiple wells formed in multiple regions of a hydrocarbon reservoir, separate the well fluids into hydrocarbon components including water, and flow the water through the water line. The multiple regions are tagged with respective tracers. Each tracer is injected into a respective region of the hydrocarbon reservoir surrounding a respective well and can flow into the respective well in response to a well breakthrough. The method also includes analyzing each sampled fluid for one or more tracers of the multiple tracers and monitoring the multiple wells for fluid breakthrough based on results of analyzing each sampled fluid.

TECHNICAL FIELD

This specification relates to hydrocarbon producing well systems, particularly with tracer detection systems.

BACKGROUND

Tracers are commonly used in the oil industry for tracking oil and water flow patterns through reservoirs. Tracers can be injected into a reservoir, and afterwards producing lines are sampled to determine concentrations of the tracers that are present at the time of their arrival. The concentrations data can be used to understand fluid flow patterns and to infer other properties of the reservoir, for example, pore volumes and flow characteristics. Data from multi-well tracer tests can provide valuable information regarding well connectivity, sweep efficiency, and identification of geologic anomalies including fracture and super K zones.

Presently, tracer breakthrough and monitoring from an individual well is done manually by collecting samples on a daily or weekly basis, transporting fluid samples to a laboratory and purifying and measuring the fluid for tracer content. This requires daily or weekly operator intervention and a long turnover time for sample measurements.

SUMMARY

The present specification describes methods and systems for determining tracer breakthrough from multiple wells simultaneously commingled into one common line at a Gas Oil Separation Plant (GOSP) with an automated, inline tracer detection system.

One aspect of the present specification features a well tracer detection system. The well tracer detection system includes a tracer detection system in fluid communication with a water line of a Gas Oil Separation Plant (GOSP) via a fluid sampling line fluidically connected to the water line. The GOSP is configured to receive commingled well hydrocarbon fluids from multiple wells. Each of the wells is in communication with a corresponding subterranean zone of a hydrocarbon reservoir. The corresponding subterranean zone is tagged with a respective tracer, and the respective tracer can flow into the well in response to a well breakthrough. The GOSP is also configured to separate the commingled well hydrocarbon fluids into hydrocarbon components including water, and flow the water through the water line. The tracer detection system receives a fluid sample from the fluid sampling line and analyzes the fluid sample to determine a presence of the tracers with which the subterranean zones corresponding to the multiple wells were tagged. The tracer detection system identifies a tracer in the fluid sample, and a well corresponding to a subterranean zone tagged with the identified tracer.

The tracer detection system can be configured to detect tracers in a parts per trillion (ppt) or parts per quadrillion (ppq) range. A volume of the fluid sample can be substantially 50 milliliters or less. The tracer detection system can include at least one of a laser-driven fluorescent spectrometer or a gas chromatography mass spectrometer. Each tracer can include at least one of an optically-tagged nanoparticle tracer or a mass-tagged nanoparticle tracer.

In some implementations, the system includes a fluid valve fluidically connecting the water line and the fluid sampling line. The fluid valve is configured to actuate to transfer the fluid sample from the water line to the fluid sampling line. The system can further include a filter positioned between the fluid sampling line and the tracer detection system. The filter is configured to remove contaminants in the fluid sample. The contaminants exclude a tracer. The system can further include a pump configured to flow the fluid sample from the fluid sampling line to the tracer detection system. The system can include a transmitter configured to transmit an identity of the identified well to a control station.

In some implementations, the system includes a computer system including one or more processors and a computer-readable medium. The computer-readable medium stores multiple first identifiers identifying the corresponding multiple wells and multiple second identifiers identifying the tracers with which the subterranean zones corresponding to the multiple wells are tagged. The computer-readable medium also stores computer instructions executable by the one or more processors to perform operations to identify the well tagged with the identified tracer. The computer system can identify a second identifier identifying the tracer identified by the tracer detection system from among the multiple second identifiers, and identify a first identifier identifying the well corresponding to the subterranzean zone tagged with the identified tracer from among the multiple first identifiers.

Another aspect of the present specfiication features a method of identifying a well breakthrough. A fluid sample is flowed from a water line of a Gas Oil Separation Plant (GOSP) to a tracer detection system. The GOSP is configured to receive commingled well hydrocarbon fluids from multiple wells. Each of the wells is in communication with a corresponding subterranean zone of a hydrocarbon reservoir. The corresponding subterranean zone is tagged with a respective tracer, and the respective tracer can flow into the well in response to a well breakthrough. The GOSP is also configured to separate the commingled well hydrocarbon fluids into hydrocarbon components including water and flow the water through the water line. The fluid sample is analyzed for a presence of the tracers in the fluid sample. A subterranean zone is identified from the subterranean zones tagged with the tracers. A well corresponding to the identified subterranean zone is identified.

The fluid sample can be pumped to the tracer detection system by using a pump. The fluid sample can be also flowed to the tracer detection system by gravitaty. In some cases, an identity of the identified well is received and a flow of the identified tracer into the identified well at the identified well is monitored in the hydrocarbon reservoir.

In some implementations, to determine the tracer in the fluid sample, the tracer is detected by performing at least one of laser-driven fluorescent spectroscopy or gas chromatography mass spectroscopy on the fluid sample. A concentration of the tracer in the fluid sample can be in the parts per trillion (ppt) or parts per quadrillion (ppq) range. Each tracer can include at least one of an optically-tagged nanoparticle tracer or a mass-tagged nanoparticle tracer.

To identify the well tagged with the determined tracer , a first computer-stored identifier that identifies the tracer and a second computer-stored identifier that is mapped to the identified first computer-stored identifier can be identified. The second computer-stored identifier identifies the well. In some cases, multiple first identifiers identifying the corresponding tracers and multiple second identifiers identifying the corresponding multiple wells are stored in a computer-readable storage medium. The multiple first identifiers includes the first computer-stored identifier, and the multiple second identifiers includes the second computer-stored identifier. One or more processors is operatively coupled to the computer-readable storage medium and configured to search the multiple first identifiers and the multiple second identifiers for a first identifier that identifies the tracer and a second identifier mapped to the first identifier.

A fluid valve can be actuated to fluidically connect the water line and a fluid sampling line to transfer the fluid sample from the water line to the fluid sampling line that is fluidically connected to the tracer detection system. Contaminants from the fluid sample obtained in the fluid sampling line can be filtered before flowing the fluid sample to the tracer detection system. The contaminants can exclude a tracer.

A further aspect of the present specification features a hydrocarbon reservoir monitoring method. Sampling fluid carried by a water line of a Gas Oil Separation Plant (GOSP) is periodically sampled. The GOSP is configured to receive commingled well hydrocarbon fluids from multiple wells formed in multiple regions of a hydrocarbon reservoir, separate the commingled well hydrocarbon fluids into hydrocarbon components including water, and flow the water through the water line. The multiple regions are tagged with multiple tracers, and each tracer is injected into a respective region of the hydrocarbon reservoir surrounding a respective well. Each tracer can flow from the respective region into the respective well in response to a well breakthrough. Each sampled fluid can be analyzed for one or more tracers of the multiple tracers and monitoring the multiple wells for fluid breakthrough based on results of analyzing each sampled fluid.

The fluid can be sampled periodically, for example, once or twice in a day. In response to analyzing a fluid sample, a presence of a tracer can be determined in the fluid sample, and a region of the hydrocarbon reservoir surrounding a well into which the tracer was injected can be identified. The well for fluid breakthrough can be then monitored.

Implementations of the present specification provide methods of determining tracer breakthrough from multiple wells simultaneously through an automated, inline tracer detection system that can be safely installed at a produced water test line from a Gas Oil Separation Plant (GOSP). By the methods, issues of high pressure, sour gas, separation procedures, return lines, and electrical supply can be minimized or eliminated.

The automated, inline detection system can be configured to trigger a flag or alert when one of the commingled wells associated with different respective tracers shows a tracer breakthrough. Once one or more tracers are detected by the detection system at the GOSP, respective individual wells feeding the commingled line can be correlated to the tracers measured by the detection system, and data can be transmitted to a base station in real time as part of the entire automated process. Once the individual wells showing breakthrough are identified, the identified wells can be tested directly at the well heads using conventional tracer monitoring methods and systems (for example, portable or handheld) to determine tracer concentration and progress.

The automated, inline detection system can be installed at the produced water stream test line downstream of the separator (after separating oil and gas from a main stream), thereby presenting minimal or no risk and hazardous high pressure sampling situations. The automated, inline detection system can include an actuated valve configured to release small quantities of the produced water into the detection system, an inline membrane separator and filter to remove any contaminants or emulsions, and a tracer detection system, based on either fluorescent mass spectrometers or gas chromatography mass spectrometers (GCMS), that are capable of detecting different tracers in a part per trillion (ppt) or part per quadrillion (ppq) level. The automated, inline detection system can also include a data acquisition module that flags any positive tracer detection and cross correlates the tracer to the appropriate well and a wireless data transfer device, for example, a transmitter, that sends this data in real time to a base control station. If no tracer is detected from the detection system, the detection system simply continues to monitor the flow stream. If there are any positive tracer flags signaling a breakthrough from one or more of the commingled wells, the data is automatically correlated to a tracer/well computer database to identify the well or wells showing breakthrough and the data transferred in real time to the base control station. When the transmitted data is reviewed and tracer breakthrough from specific wells are identified, conventional well head tracer monitoring can be deployed.

The technology can avoid time consuming procedure of monitoring every well injected with tracers on a daily or weekly basis to detect tracer breakthrough individually and manually. Instead, the technology enables to automatically determine tracer breakthrough from multiple commingled wells without expensive, high risk modifications to every well head for tracer detection. This can save considerable amount of man power and hours and potentially allow for tracers to be deployed at a reservoir or field scale at an efficient and economical way. In addition, enabling field-wide implementation of tracers studies can provide important information about fluid movements within the reservoir, which can result in optimized water injection schemes and informative infill drilling, and improved reservoir management strategies and ultimately increasing oil recovery.

The details of one or more implementations of the subject matter of this specification are set forth in the accompanying drawings and associated description. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.

DETAILED DESCRIPTION

FIG. 1Ais a schematic diagram illustrating an example of a hydrocarbon producing well system100provided by the present specification. The well system100can be arranged at a well site. The well system100includes multiple wells102a,102b,102cthat are separate from each other but located within the same well site, that is, formed in the same hydrocarbon reservoir from which hydrocarbons are being extracted.

Each well102a,102b, or102cextends from a respective well head104a,104b, or104cat a terranean surface (or the Earth's surface)101through a respective subterranean zone of interest106a,106b, or106cin a hydrocarbon reservoir103. For example, the well102aextends from the well head104aat the terranenan surface101through the subterranean zone106ain the hydrocarbon reservoir103. The well102a,102b, or102ccan be any suitable type of well, for example, a well including a single wellbore like the well102aor102c, or a well including multiple wellbores like the well102b. The well102a,102b, or102cis configured to produce hydrocarbon components, for example, gas, oil, water, or any suitable combinations, from the subterranean zone106a,106b, or106c, respectively. The subterranean zone106a,106b, or106csurrounds the well102a,102b, or102c, respectively. Each well102a,102b, or102cis in communication, for example, fluidically, with a corresponding subterranean zone106a,106b, or106c.

Individual tracers108a,108b,108care injected into the respective subterranean zones106a,106b,106c. In response to a well breakthrough of the well102a,102b, or102c, the tracers108a,108b, or108ccan flow into the respective well102a,102b, or102c, respectively. The tracers108a,108b,108ccan be different from each other, so that individual tracers in each well can be used to uniquely identify a respective well breakthrough of the well. That is, each well102a,102b, or102ccorresponds to a subterranean zone106a,106b,106ctagged with respective tracers108a,108b, or108c. Each tracer108a,108b, or108cis associated with (or corresponds to) a respective well102a,102b, or102c.

In some cases, the tracers are optically-tagged nanoparticle tracers and can be detected by optical methods, for example, laser-driven fluorescent spectroscopy or Raman spectroscopy. Nanoparticle tracers with different sizes (lengths, diameters) or shapes or both, may have different fluorescence spectrums (for example, emission wavelengths), Raman spectrums, or resonance spectrums. In some cases, the tracers are mass-tagged nanoparticle tracers and can be detected by mass spectrometers, for example, gas (or liquid) chromatography mass spectrometers (GCMS or LCMS). The tracers can also be any other suitable nanoparticle tracers. For example, this detection scheme could be equally applicable for molecule base chemical tracers, DNA strands tags, and bio-based tracers.

Hydrocarbon liquids produced from the multiple wells102a,102b,102ccan be input through respective lines109a,109b,109cto a combiner110that is configured to combine the hydrocarbon liquids to be commingled well hydrocarbon fluids. The commingled well hydrocarbon fluids are further sent from the combiner110through a common line115to a separator122of a Gas Oil Separation Plant (GOSP)120. The separator122can be a residual oil/water separator or an oil/gas/water separator. As illustrated inFIG. 1A, the separator122is configured to separate the commingled well hydrocarbon fluids received from the combiner110into separated lines121,123,125to get separated hydrocarbon components comprising gas, oil, and water.

A fluid sampling line127is configured to fluidically couple to the water line125of the GOSP120to obtain a fluid sample from the water flowing through the water line125. In some implementations, a fluidic valve124fluidically connects the water line125and the fluid sampling line127and is configured to actuate to transfer the fluid sample from the water line125to the fluid sampling line127. The fluid sample can be small quantities of produced water. For example, a volume of the fluid sample can be substantially 50 milliliter (mL) or less. The fluidic valve124can be actuated periodically, for example, once or twice per day, or in response to a request.

The GOSP120includes a tracer detection system130configured to identify one or more tracers in the fluid sample. The tracer detection system130is fluidically coupled to the fluid sampling line127and configured to receive the fluid sample from the fluid sampling line127, analyze the fluid sample to determine a presence of the multiple tracers108a,108b,108cwith which the subterranean zones106a,106b,106ccorresponding to multiple wells102a,102b,102cwere tagged, identify, in response to analyzing the fluid sample, a tracer in the fluid sample, and identify, in response to identifying the tracer in the fluid sample, a well corresponding to a subterranean zone tagged with the identified tracer. The tracer detection system130is configured to detect tracers in a ppt or ppq range. The tracer detection system130can be an automated, inline measurement system installed downstream of the separator122in the GOSP120. As discussed further inFIG. 1Blater, if the tracers are nanoparticles with fluorescence materials, the tracer detection system130can detect an optical spectrum (or an emission spectrum) of the fluid sample excited by a white LED light. It can be determined the presence of the multiple tracers based on the optical spectrum and further determined individual tracers based on respective resonance wavelengths (or emission wavelengths) in the optical spectrum. If the tracers are mass-tagged nanoparticle tracers, the tracer detection system130can detect a mass spectrum of the fluid sample. It can be determined the presence of the multiple tracers based on the mass spectrum and further determined individual tracers based on respective signature peaks in the mass spectrum.

In some implementations, the tracer detection system130is configured to detect a particular tracer tagged to a particular subterranean zone corresponding to a particular well. For example, if the particular tracer includes nanoparticles with a fluorophore material, in a tracer detection test, the tracer detection system130can use a laser source with a wavelength within an absorption range of the fluorescence material to illuminate the fluid sample and to detect an emission spectrum of the fluidic sample. If the emission wavelength in the detected emission spectrum matches with the emission wavelength for the fluorophore material, it can be determined that the fluid sample includes the particular tracer. In some cases, the tracer detection system130runs different tracer detection tests on the fluid sample for identifying different tracers, for example, in parallel or in series.

In some implementations, the GOSP120includes a filter126positioned between the fluid sampling line127and the tracer detection system130. The filter126is configured to remove contaminants or emulsions in the fluid sample. The contaminants or emulsions exclude tracers. The filter126can be an inline filter cartridge and include one or more water purification materials.

In some implementations, the fluidic sample or the filtered fluidic sample from the filter126is fed to the tracer detection system130gravitationally. In some implementations, the GOSP120includes a pump128configured to flow the fluid sample from the fluid sampling line127to the tracer detection system130. The pump128can be arranged after (or before) the filter126between the fluidic sampling line127(or the fluidic valve124) and the tracer detection system130. The pump128can be a small capillary pump.

FIG. 1Bis a schematic diagram illustrating an example of the tracer detection system130. The tracer detection system130includes a flow cell132configured to receive the fluid sample from the fluid sampling line127, for example, through the filter126or the pump128or both. The flow cell132can be a container, for example, a cuvette, positioned on a holder. The tracer detection system130includes a tracer detector134configured to detect any tracers in the fluid sample. The tracer detector134can be configured to detect a number of different tracers in a ppt or ppq level. The number can be more than 10, 20, 50, or 100.

As noted earlier, in some examples, the tracers are optically-tagged nanoparticle tracers, for example, nanoparticles with fluorescent materials, quantum dots, or metal nanoparticles. The tracers can emit optical signals when excited by light, and the optical signals can be fluorescent signals or Raman scattering signals. Different tracers can have different resonance wavelengths or signature peaks. The tracer detection system130can include a light source for fluorescent or Raman illumination, for example, a light-emitted-diode (LED) lamp, to inject light on the flow cell132. The tracer detector134can be a spectrometer configured to measure an optical spectrum of the emitted optical signals. Based on resonance wavelengths or signature peaks in the optical spectrum, one or more tracer types can be identified. For example, the tracers108a,108b, and108ccan be nanoparticles with different fluorophores with resonance wavelengths of 450 nanometer (nm), 530 nm, 630 nm, respectively. A white LED light can be used to illuminate the fluid sample. If the optical spectrum (or the emission spectrum) measured by the tracer detector134includes a resonance wavelength of 530 nm and a resonance wavelength of 630 nm, it can be determined that the fluid sample includes the tracers108band the tracers108c.

In some examples, the tracers are mass-tagged nanoparticle tracers. The tracer detector134can be a mass spectrometer, for example, a gas (or liquid) chromatography mass spectrometers (GCMS or LCMS), that can uniquely detect the mass-tagged nanoparticle tracers based on their mass spectrums. For example, when a fluid sample is tested by the mass spectrometer, the mass spectrum includes signature peaks of the tracers108aand108b. Based on the signature peaks, it can be determined the presence of tracers and further determined that the fluid sample includes the tracers108aand the tracers108b.

Data output from the tracer detector134, for example, fluorescence or Raman spectrums, mass spectrums of the fluid sample, can be transmitted to a computer system140via a connection135. The connection135can be a wired line or a wireless connection. The tracer detector134can continuously monitor the fluid sample to detect tracer breakthrough without human intervention. The data can be continuously transmitted to the computer system140.

The computer system140is configured to analyze the data to determine a presence of the multiple tracers108a,108b,108cwith which the subterranean zones106a,106b,106ccorresponding to the multiple wells102a,102b,102cwere tagged. As discussed earlier, this determination can be based on the resonance wavelengths (or signature peaks) in the fluorescence spectrums (or mass spectrums). Based on the resonance wavelengths or signature peaks, the computer system140can further identify one or more tracers in the fluid sample. If there is a tracer identified, it indicates that the tracer flows into a well in response to a well breakthrough of the well (or called a tracer breakthrough).

In some implementations, the computer system140includes one or more processors142and a memory (for example, a computer-readable medium)144. The memory144stores multiple first identifiers identifying the corresponding multiple wells and multiple second identifiers identifying multiple tracers with which the subterranean zones corresponding to the multiple wells are tagged. That is, each first identifier identifying a well is associated with (or mapped to) a respective second identifier identifying a tracer with which a subterranean zone corresponding to the well is tagged. The memory stores a database including the associations (or mappings) of the first identifiers with the second identifiers.

The memory144can also store computer instructions executable by the one or more processors142to perform operations to identify the well corresponding to the subterranean zone tagged with the identified tracer. The computer system140can be configured to identify, from among the multiple second identifiers, a second identifier identifying the tracer identified and then identify, from among the multiple first identifiers, a first identifier identifying the well corresponding to the subterranean zone tagged with the identified tracer, based on an association between the first identifier and the second identifier. In other words, the computer system140can identify a second computer-stored identifier that identifies the tracer and then identify a first computer-stored identifier that is associated with (or mapped to) the identified second computer-stored identifier. The first computer-stored identifier identifies the well.

The computer system140can flag any positive tracer detection and cross-correlate the tracer to an associated well. The computer system140can determine whether there are any positive tracer flags signaling a breakthrough from one or more of the commingled wells102a,102b,102c. If no tracer is detected, the tracer detection system130continues to sample and monitor for any breakthrough. If tracer(s) breakthrough is detected, the corresponding well(s) is identified by referencing the stored computer database in the memory144.

In some implementations, the computer system140includes a transmitter146configured to transmit, for example, wirelessly, an identity of the identified well to a control station, as discussed in further details inFIG. 2. The transmitter146can also transmit the measured data of the tracer detector134, for example, the optical spectrums or mass spectrums, to the control station. At the control station, the transmitted data can be reviewed and tracer breakthrough from specific wells can be identified, and conventional well head tracer monitoring systems can begin as per standard field operations. The control station can also store a database associating tracers to wells. In some examples, the control station can identify a tracer based on the measured data and then identify a well based on the identified tracer and the database. In some examples, the control station can receive an identify of an identified well identified by an identified tracer and send a request or command to monitor, at the identified well in the hydrocarbon reservoir, a flow of the identified tracer into the identified well.

In some examples, the computer system140is included in the tracer detection system130, as illustrated inFIG. 1B. In some other examples, the computer system140is externally coupled to the tracer detection system130. The computer system140can be in the GOSP120or external to the GOSP120. In some examples, the transmitter146is included in the computer system140, as illustrated inFIG. 1B. In some other examples, the transmitter146is externally coupled to the computer system140but included in the tracer detection system130or in the GOSP120.

FIG. 2is a schematic diagram illustrating an example200of transmission between hydrocarbon producing well systems202a,202band a base station206. The well systems202a,202bcan be at different well sites separate from each other. The well system202aor202bcan be the well system100ofFIG. 1A. Although two well systems are depicted, it is appreciated that the base station206can communicate with a number of well systems. In such a way, the base station206can remotely monitor (and control) numerous well systems at numerous well sites.

Each well system202aor202bcan include a GOSP system220aor220b, respectively, configured to receive commingled well hydrocarbon fluids from multiple wells230aor230b, respectively. The GOSP system220aor220bcan be the GOSP120ofFIG. 1A. The GOSP system220aor220bcan periodically sample fluid carried by a water line of the GOSP220aor220bto analyze for one or more of multiple tracers tagged to multiple subterranean zones corresponding to the multiple wells and monitor the multiple wells for fluid breakthrough based on results of analyzing each sampled fluid. The GOSP system220aor220beach can include a transmitter, for example, the transmitter146ofFIG. 1B, and transmit data, for example, measured data or identified wells or both, to the base station206, for example, wirelessly.

In some implementations, the GOSP system220aor220bwirelessly transmits data to the base station206through a network204. The network204can include a large computer network, such as a local area network (LAN), wide area network (WAN), the Internet, a cellular network, a satellite network, a mesh network, one or more wireless access points, or a combination thereof connecting any number of mobile clients, fixed clients, and servers.

In some implementations, the data is transmitted from each GOSP system220aor220bthrough an access point210that can be mounted on a tower208. The tower208can include an existing telecommunications tower. In some examples, data can be transmitted between the access point210and the GOSP systems220a,220bbased on a local network, for example, a low power data network, a cellular network, a satellite communication network, or any combination thereof In some examples, the access point210provides a radial coverage that enables the access point210to communicate with numerous well systems, such as the well system202aor202b. In some examples, the access point210further communicates with the network204using cellular, satellite, mesh, point-to-point, point-to-multipoint radios, terrestrial or wired communication, or any combination thereof.

FIG. 3Ais a flowchart of an example process300of determining tracer breakthrough from multiple wells commingled at a GOSP. The GOSP can be the GOSP120ofFIG. 1A. The GOSP is configured to receive commingled well hydrocarbon fluids from the multiple wells formed in multiple regions of a hydrocarbon reservoir and separate, for example, by the separator122of FIG,1A, the well fluids into hydrocarbon components including water. The GOSP is configured to flow the water through a water line and sample the produced water for detection.

Tracer breakthrough is detected from the multiple commingled wells at the GOSP (302). As noted earlier, each well corresponds to a region of the hydrocarbon reservoir surrounding with the well. A respective tracer is injected into the region and flows into the well in response to a well breakthrough. That is, each well is associated with a tracer tagged to a region corresponding to the well.

The detection302can be automatically performed at the GOSP. A valve, for example, the valve124ofFIG. 1A, is actuated to receive a fluid sample (310) from the water line, for example, periodically such as once or twice per day. The sampled fluid can have a volume of substantially 50 mL or less. The fluid sample is filtered (312), for example, by the filter126ofFIG. 1A. The filtered sample can be by gravity or pumped, for example, by the pump128ofFIG. 1B, to a tracer detection system of the GOSP, for example, the tracer detection system130ofFIGS. 1A-1B.

Tracer measurement is performed on the fluid sample (314) by the tracer detection system. The tracer measurement can be based on laser-driven fluorescent or Raman spectroscopy or mass spectrometer such as GCMS on the fluid sample. Each tracer can be at least one of an optically-tagged nanoparticle tracer or a mass-tagged nanoparticle tracer. The concentration of the tracer in the fluid sample can be in the ppt or ppq range.

The measured data is transmitted (316), for example, from the tracer detection system to a computer system, for example, the computer system140ofFIG. 1B. The computer system determines whether there is any tracer breakthrough (318), for example, a tracer flowing into a well in response to a well breakthrough of the well. If the computer system determines that there is no tracer detected in the fluid sample, the process300goes back to step310for continuously sampling the fluid from the water line of the GOSP. If the computer system determines that there are one or more tracers detected in the fluid sample, the computer system matches the detected tracers to corresponding wells (320).

FIG. 3Bis a flowchart of an example process350of determining a well associated with an identified tracer. The process350can be performed by the computer system and implemented as the step320.

A tracer is identified based on measured data (352). The measured data can be from the tracer detection system. A first identifier identifying the identified tracer is determined in a database (354). The database can be stored in the computer system and associates or maps different tracers to respective wells corresponding to respective regions tagged with the tracers. A second identifier associated with the first identifier in the database is determined (356), for example, based on the association stored in the database. Then a well identified by the determined second identifier is determined (358).

Referring back toFIG. 3A, after the well(s) associated with the identified tracers in the fluid sample is (or are) identified, data including the identified well(s) or the measured data or both can be transmitted, for example, wirelessly, to a base station. In some cases, the data can be transmitted to the base station in real time as part of the entire automated process302. That is, as soon as the tracer detection system obtains the data, the tracer detection system transmits the data to the base station. The base station can analyze the identified well(s) or the measured data or both and start a well head tracer monitoring system, for example, per standard field operations. Well head sampling of wells showing breakthrough is begun, for example, manually (304). In some implementations, steps318and320can be performed by the based station based on the measured data and a stored database associating tracers to wells.

This process300eliminates the need for constant manual testing of all injected wells daily for signs of tracer breakthrough and does not require expensive, high risk modifications to every well head for tracer detection. In this process300, several tracers can be monitored by a continuous periodic sampling system safely (for example, an ongoing sampling program is running where samples are taking periodically), and manual testing at the well head can be delayed until tracer breakthrough is first detected at the GOSP. This process300can allow for field wide monitoring systems.

FIG. 4is a block diagram400of an exemplary computer402used for determining tracer breakthrough from multiple wells commingled at a GOSP according to an implementation. The computer402can be the computer system140ofFIG. 1B. The illustrated computer402is intended to encompass any computing device such as a server, desktop computer, laptop or notebook computer, wireless data port, smart phone, personal data assistant (PDA), tablet computing device, or one or more processors within these devices, including both physical and virtual instances of the computing device. Additionally, the computer402may comprise a computer that includes an input device, such as a keypad, keyboard, touch screen, or other device that can accept user information, and an output device that conveys information associated with the operation of the computer402, including digital data, visual and audio information, or a graphical user interface (GUI).

The computer402can serve as a client, network component, a server, a database or other persistency, or a component of a computer system for determining tracer breakthrough from multiple wells commingled at a GOSP. The illustrated computer402is communicably coupled with a network430. The network430can be the network204ofFIG. 2. In some implementations, one or more components of the computer402may be configured to operate within a cloud-computing-based, local, global, or other environment.

At a high level, the computer402is an electronic computing device operable to receive, transmit, process, store, or manage data and information associated with determining tracer breakthrough from multiple wells commingled at a GOSP. According to some implementations, the computer402may also include or be communicably coupled with an application server, e-mail server, web server, caching server, streaming data server, business intelligence (BI) server, or other server.

The computer402can receive requests over network430from a client application (for example, executing on another computer402) and respond to the received requests by processing the said requests in an appropriate software application. In addition, requests may also be sent to the computer402from internal users (for example, from a command console or by other appropriate access method), external or third parties, other automated applications, as well as any other appropriate entities, individuals, systems, or computers.

Each of the components of the computer402can communicate using a system bus403. In some implementations, any or all the components of the computer402, both hardware and software, may interface with each other or the interface404over the system bus403using an application programming interface (API)412or a service layer413. The API412may include specifications for routines, data structures, and object classes. The API412may be either computer language-independent or -dependent and refer to a complete interface, a single function, or even a set of APIs. The service layer413provides software services to the computer402and other components (whether or not illustrated) that are communicably coupled to the computer402. The functionality of the computer402may be accessible for all service consumers using this service layer. Software services, such as those provided by the service layer413, provide reusable, defined business functionalities through a defined interface. For example, the interface may be software written in any suitable language providing data in extensible markup language (XML) format or other suitable format. While illustrated as an integrated component of the computer402, alternative implementations may illustrate the API412and the service layer413as stand-alone components in relation to other components of the computer402and other components (whether or not illustrated) that are communicably coupled to the computer402. Moreover, any or all parts of the API412and the service layer413may be implemented as child or sub-modules of another software module, enterprise application, or hardware module without departing from the scope of this specification.

The computer402includes an interface404. Although illustrated as a single interface404inFIG. 4, two or more interfaces404may be used according to particular needs, desires, or particular implementations of the computer402and functionality for determining tracer breakthrough from multiple wells commingled at a GOSP. The interface404is used by the computer402for communicating with other systems in a distributed environment that are connected to the network430. Generally, the interface404comprises logic encoded in software and hardware in a suitable combination and operable to communicate with the network430. More specifically, the interface404may comprise software supporting one or more communication protocols associated with communications such that the network430or interface's hardware is operable to communicate signals within and outside of the illustrated computer402.

The computer402includes a processor405. The processor405can be the processor142ofFIG. 1B. Although illustrated as a single processor405inFIG. 4, two or more processors may be used according to particular needs, desires, or particular implementations of the computer402. Generally, the processor405executes instructions and manipulates data to perform the operations of the computer402. Specifically, the processor405executes the functionality for determining tracer breakthrough from multiple wells commingled at a GOSP.

The computer402also includes a memory406that holds data for the computer402and other components that can be connected to the network430. The memory406can be the memory144ofFIG. 1B. For example, memory406can be a database storing data consistent with this specification. Although illustrated as a single memory406inFIG. 4, two or more memories may be used according to particular needs, desires, or particular implementations of the computer402and functionality to determine tracer breakthrough from multiple wells commingled at a GOSP. While memory406is illustrated as an integral component of the computer402, in alternative implementations, memory406can be external to the computer402.

The application407is an algorithmic software engine providing functionality according to particular needs, desires, or particular implementations of the computer402, particularly with respect to functionality required for determining tracer breakthrough from multiple wells commingled at a GOSP. For example, application407can serve as one or more components, modules, and applications described with respect to any of the figures. Further, although illustrated as a single application407, the application407may be implemented as multiple applications407on the computer402. In addition, although illustrated as integral to the computer402, in alternative implementations, the application407can be external to the computer402.

There may be any number of computers402associated with, or external to, a computer system containing computer402, each computer402communicating over network430. Further, the terms “client,” “user,” and other appropriate terminology may be used interchangeably as appropriate without departing from the scope of this specification. Moreover, this specification contemplates that many users may use one computer402, or that one user may use multiple computers402.

In some implementations, any or all of the components of the computing system, both hardware and software, may interface with each other or the interface using an application programming interface (API) or a service layer. The API may include specifications for routines, data structures, and object classes. The API may be either computer language-independent or -dependent and refer to a complete interface, a single function, or even a set of APIs. The service layer provides software services to the computing system. The functionality of the various components of the computing system may be accessible for all service consumers via this service layer. Software services provide reusable, defined business functionalities through a defined interface. For example, the interface may be software written in any suitable language providing data in any suitable format. The API and service layer may be an integral or a stand-alone component in relation to other components of the computing system. Moreover, any or all parts of the service layer may be implemented as child or sub-modules of another software module, enterprise application, or hardware module without departing from the scope of this specification.

Accordingly, the earlier provided description of example implementations does not define or constrain this specification. Other changes, substitutions, and alterations are also possible without departing from the spirit and scope of this specification.