WO2024258899A1 - Plate-forme de diagnostic directement reliée à une formation souterraine - Google Patents

Plate-forme de diagnostic directement reliée à une formation souterraine Download PDF

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Publication number
WO2024258899A1
WO2024258899A1 PCT/US2024/033495 US2024033495W WO2024258899A1 WO 2024258899 A1 WO2024258899 A1 WO 2024258899A1 US 2024033495 W US2024033495 W US 2024033495W WO 2024258899 A1 WO2024258899 A1 WO 2024258899A1
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Prior art keywords
sample
valve
instrument
housing
combination
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PCT/US2024/033495
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English (en)
Inventor
John Jeffrey PECHINEY
Jason Michael WATFORD
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Patina Ip LLC
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Patina Ip LLC
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
    • E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
    • E21B49/088—Well testing, e.g. testing for reservoir productivity or formation parameters combined with sampling
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/26—Oils; Viscous liquids; Paints; Inks
    • G01N33/28—Oils, i.e. hydrocarbon liquids
    • G01N33/2823—Raw oil, drilling fluid or polyphasic mixtures
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/20—Computer models or simulations, e.g. for reservoirs under production, drill bits

Definitions

  • Chemical tracers are soluble in the fluid they are meant to trace: oil, natural gas, and water. Tracer composition is tailored to be non-reactive with reservoir fluids or reservoir rocks, stable at downhole temperatures, and detectable at low concentrations, typically in parts per billion (ppb). Tracers are injected into the reservoir during hydraulic fracture stimulation or secondary recovery injections. Once placed in the reservoir, tracers will remain dissolved within the oil, gas, or water as the fluid is produced. Samples are taken of these produced fluids, transported to a lab, and analyzed for the tracer chemicals present and their concentration. Tracer chemical concentrations are proportional to the amount of fluid produced. The chemical identity and concentration test results are typically organized in time series charts and help inform models of the reservoir. The collection of samples, transport, lab analysis, and results reported back to the end user of the information has been in use with no noteworthy decrease in processing time for about half a century. The chemical identity and concentration test results inform models of the reservoir into two major categories: flow profiles and interwell communication.
  • Flow Profiles describe how portions of a well are flowing compared to each other. Profiles can be balanced, all segments are flowing evenly, or non-balanced, such as heel- dominated, where the heel portion of a horizontal well is flowing more than the toe portion. Flow profiles can be affected by hydraulic fracture treatment design and execution, changing reservoir geology, physical obstructions inside the wellbore, or reservoir drawdown intensity. They can and will change over time. Figure 1 shows a balanced flow profile from a well traced with 30 tracers. These data are invaluable as they inform technical personnel what is affecting the flow of the well, how to address it, and how it changes over time.
  • Interwell communication describes how stimulation fluids flow in relation to wells over time. Tracers pumped in one well and recovered in another implies fluid communication through the reservoir. In secondary recovery operations, long-term well communication is preferred so that the injected fluids sweep more hydrocarbons.
  • interwell communication can describe how the fracture system is propagating through the reservoir and traveling to another well, how natural fracture swarms or faults may magnify communication from one well to another, and how depleted reservoir rock affects fluid travel.
  • Figure 2 shows the interwell communication of two wells each traced with four tracers. There are large concentrations of the tracers pumped in Well 1 being recovered in Well 2. On the other hand, there are small concentrations of tracers being recovered in Well 1 that were pumped in Well 2. The figure shows the preferential direction of the fluid, Well 1 to Well 2.
  • Geochemical analysis is the component analysis of water, oil and gas fluids produced from the reservoir. Samples of these produced fluids are taken from the wellsite, transported to a lab, and analyzed in a way similar to chemical tracers. The values and trends of the components over time are beneficial to the well operator for how much hydrocarbon is in place, how the profile of the produced hydrocarbons changes over time, and how offset wells in the reservoir affect the hydrocarbons being produced. Geochemical analysis is used to allocate production for a group of wells that are in communication with each other from different producing formations. These data are also used to inform the reservoir model.
  • engineers can use continuous oil and gas geochemical analysis to understand how a collection of wells in different reservoirs with different vertical depths are interacting.
  • a well begins production, its hydrocarbons come from the near-wellbore region. Then as the well begins to drain more of the reservoir the mechanism of production changes and the hydrocarbons flow from farther reaches of the reservoir into the wellbore.
  • a wellbore in one reservoir may produce hydrocarbons from another reservoir depending on time, stimulated reservoir volume, well flowing conditions, and depletion effects. How these effects change over time are useful for engineers to design wellbore layouts, hydraulic fracturing treatments, flowback strategies, well interventions, and long-term production strategies.
  • Figure l is a schematic of a balanced flow profde for a 30 stage hydraulically fractured well.
  • Figure 2 is a schematic of interwell communication of two wells.
  • Figure 3 is a diagnostic platform schematic including sample flow from a wellhead to instruments in an equipment rack.
  • Figure 4 is a plot of tracer and cation concentrations as a function of time.
  • Figure 5 is a plot of tracer and cation concentrations as a function of time.
  • Figures 6A and 6B are schematic views of multiplexing valve inputs and outputs with a multiport dead-end configuration.
  • Figures 7A and 7B are schematic views of multiplexing valve inputs and outputs with a multiport flow through configuration.
  • Figure 9 is a diagnostic platform schematic aligned with chromatograms and results.
  • Figure 10 is a plot of continuous water tracer and water cation concentrations.
  • Figure 11 is a plot of continuous oil tracer and oil component concentrations.
  • Figure 12 is a plot of continuous gas tracer and gas component concentrations.
  • Embodiments herein relate to an apparatus, system, compositions, and method to observe a sample from a wellbore traversing a subterranean formation including continuously collecting a sample from the wellbore, wherein the collecting includes a separator and a valve, observing the sample in an instrument for characterizing the sample, wherein the instrument is enclosed in a housing, reporting a result of the observing, and controlling the temperature of the housing, instrument, sample, valve, or a combination thereof.
  • Continuously collecting a sample may include continuously flowing a portion of the sample through a port of the valve.
  • the valve may be a multiport valve and it may have a flow through configuration. In some embodiments, the multiport valve has eight ports and it may accept samples from two wellbores.
  • the instrument may be a mass spectrometer with electron capture, flame ionization with thermal conductivity, flame ionization with mass spectrometer, mass spectrometer with UV-Vis, or a combination thereof.
  • reporting may include a satellite system, a cellular router, a controller, or a combination thereof. It may occur once every twenty -four hours and it may include results from two or more instruments. In some embodiments, reporting includes results from two or more instruments within the same hour.
  • the housing may include a heating and cooling unit, a power supply, a water reservoir, operation gas, calibration gas, a sample outlet, or a combination thereof. In some embodiments, the separator separates the sample into gas, oil, water, or a combination thereof.
  • Embodiments herein relate to an apparatus, system, compositions, and method to observe a sample from a wellbore traversing a subterranean formation including a sample continuously collected from the wellbore, wherein the sample flows through a separator and a valve, an instrument that characterizes the sample and records results of the characterizing, wherein the instrument is enclosed in a housing, a controller that controls the temperature of the housing, and a reporting device comprising a satellite system or a cellular router.
  • Embodiments herein relate to collecting continuous information at the wellsite that informs the management of a producing reservoir.
  • engineers By directly connecting a diagnostic platform to the reservoir, engineers have a system to optimize well performance, map well- to-well connections, quantify the impact of well design changes, quantify the impact of hydraulic fracturing on offset wells, track production components and how they change over time, delineate depletion effects, and better produce mature fields under secondary recovery.
  • continuous geochemical analysis is applied to hydrocarbon samples in early time production and assumes hydrocarbon production is coming from the near-wellbore region. This serves as a baseline to be used throughout the project. As the project continues, the component analysis is applied to each wellbore in the project for several weeks and compared to each well’s baseline. Using analytical techniques such as regression analysis the results of later time samples are compared to the early time results to calculate how much hydrocarbon a well is producing from its baseline compared to the other wells in different reservoirs nearby. These results are reported to the engineer on a continuous basis and correlated with other field data to understand the effects of field operations in real time. These data are then applied to future well designs and production strategies and allow for continuous optimization of the reservoir and overall resource recovery.
  • Tracer and geochemical data sets are valuable to the reservoir model when combined.
  • a group of wells with interwell tracer communication will have varying degrees hydrocarbon component communication over time. Tracer communication is typically observed first followed by communication from light hydrocarbons then followed communication from heavier hydrocarbons. The speed and direction of these trends coupled with well production allows engineers to effectively tune their reservoir model in a development area. This enables optimum reservoir performance and ultimately the asset’s performance.
  • the diagnostic platform is a mobile system with up to six instruments assembled in an enclosed trailer. It is located at the wellsite and directly connected to the production fluids of several wells, typically ten or less.
  • the enclosed trailer will contain insulation, a heating/cooling system, operational fluids, and gases necessary to run the instruments, a battery backup system configured with a network card, and a communications system to transfer the raw data onto a cloud server.
  • a schematic of the diagnostic platform is shown in Figure 3.
  • the enclosed trailer is approximately 6’x 10’x 6’ and is insulated with foam wallboard that is 1” thick or sprayed with polyurethane foam that is %” tol ’A” thick.
  • the heating/cooling system is a single-room portable air conditioner and heater and is approximately 17” x 13” x 27”.
  • the communications system is a satellite system such as a Starlink or a cellular router with a boosting antenna of size 12” x 3” x 4”.
  • the heating/cooling system can be purchased from Lowes or Home Depot as well as the insulation.
  • the cellular router and antenna can be purchased from any industrial communications equipment distributor.
  • Starlink can be purchased from SpaceX.
  • the enclosed trailer can be purchased from any of the hundreds of trailer manufacturers.
  • the battery backup system can be purchased from APC of West Kingston, Rhode Island.
  • An equipment rack that contains up to six instruments is used for analyzing the production streams for tracer concentrations, water, or hydrocarbon components. Each instrument will be connected to the production fluid which it is meant to analyze. The trailer containing the instruments will be spotted as close as possible to the production equipment on the wellsite and powered by utility power, a generator, or a light tower.
  • a three-phase well one that produces oil, natural gas, and water, has a three-phase separator. As the comingled oil, gas and water is produced from the reservoir it flows up the wellbore, through the wellhead, through a flowline and into the three-phase separator. The separator will separate the comingled fluid into oil, gas, and water streams.
  • a small line from each stream will be connected to the instruments. Since there are three main streams, oil, water, and gas, and up to six instruments, the small line from each stream will need to split into two small lines for a total of six small lines, two for gas, two for water and two for oil.
  • the small lines can be 1/16”, 1/8” stainless steel, or 1/8” PEX or PEEK. These materials can be purchased from Grainger of Lake Forest, Illinois.
  • a gas chromatograph with a flame ionization detector or thermal conductivity detector can be used.
  • a gas chromatograph with a mass spectrometer or electron capture detector can be used.
  • a gas chromatograph with a flame ionization detector or mass spectrometer can be used.
  • a gas chromatograph with a mass spectrometer or electron capture detector can be used.
  • a liquid chromatograph with a UV-VIS or mass spectrometer detector can be used.
  • a liquid chromatograph with a UV-VIS or mass spectrometer detector can be used.
  • fluorinated benzoates such as sodium 2-fluorobenzoate, sodium 3-fluorobenzoate, sodium 2-(trifluoromethyl)benzoate, and the like
  • fluorinated benzoates such as sodium 2-fluorobenzoate, sodium 3-fluorobenzoate, sodium 2-(trifluoromethyl)benzoate, and the like
  • water tracers are used as water tracers.
  • napthaelene sulfonic acids such as 1 -naphthalene sulfonate, 2-naphthalene sulfonate, 1,5 -naphthalene disulfonate, 1,6-naphthalene disulfonate, 2,6-naphthalene disulfonate, and the like are used as water tracers.
  • the tracers stay dissolved in the stimulation fluid and travel into the formation. Once in the reservoir any formation water contacted by the stimulation treatment will mix with the stimulation fluid. The tracer will stay dissolved in this mixture until they are produced up the wellbore. The tracers are often detected in produced water for several months at concentrations in the parts per billion.
  • Formation water was formed millions of years ago with organic content and water. Formation water can contain salts, minerals and other solids. The layers of subterranean rock were pressurized and cooked resulting in different compositions. Formation water can have high or low salt contents, high or low mineral contents or high or low solids concentrations.
  • the cations being produced from the subterranean formation are measured and quantified. These dissolved salts, sodium, magnesium, calcium, potassium serve as markers for a reservoir and its water content. By measuring the salt content in real time over several months well operators can determine how the formation is producing and if it is comingling with our formations connected from the stimulation treatment. From initial startup of a well the salt content of the produced water is low as the stimulation fluids are being recovered. Once the stimulation fluids begin to decline cation concentrations increase then plateau and at the native formation water concentration.
  • water tracer concentrations and cation concentrations are inversely proportional.
  • a well When a well is on initial flowback its tracer concentrations are high since it hasn’t produced back the tracer mass injected into it. If fresh water was used as a stimulation fluid, cation concentrations will be low since the well is producing its stimulation fluid. Over time tracer concentrations begin to drop and more and more mass of the tracer is produced. Cation concentrations increase as a result of stimulation fluid production declining and formation water increasing since formation water typically contains high cation concentrations.
  • This inverse relationship is a useful diagnostic in determining when a part of the wellbore is producing larger amounts of formation water.
  • Figure 4 shows the inverse relationship of tracer concentrations vs cation concentration.
  • Figure 5 shows a part of the well that is producing more formation water than the other segments over several months since the cation concentrations are high and the tracer concentration is low.
  • each instrument is equipped with a multiport valve.
  • Each multiport valve will have several inlets and one outlet. The valve is electronically actuated and rotates to allow fluids to flow from the desired well.
  • a multiport valve with a dead-end configuration can be used for the gas phase analysis.
  • a multiport valve with a flow-through configuration can be used for water and oil analysis. Either multiport valve configuration can be purchased from Agilent of Santa Clara, California.
  • the multiport valve has multiple inputs and one output. By closing off all the inputs but one, known as a dead-end configuration, then cycling to the next input, multiple flow streams can be sampled with one instrument.
  • Figures 6A and 6B show the flow paths of an eight-input multiport valve. In Figure 6A, the fluids are coming into input 1 and exiting through the output at the center of the valve. Inputs 2-8 remain closed to flow, i.e. are dead-end. In Figure 6B, the valve has switched to connect input 2 while closing inputs 3- 8 and 1. In some embodiments it is advantageous to use a flow-through valve configuration.
  • Figures 7A and 7B show the flow paths of the flow-through valve where the fluids coming into input 1 exit through the center and flow to the instrument. Unlike the dead-end configuration, inputs 2-8 remain open to flow and, in some embodiments, are vented. For liquid sample lines such as water or oil a flow-through configuration is necessary to maintain flow through the sample lines.
  • FIG. 8 A diagnostic platform schematic with two wells is shown in Figure 8.
  • Well 1 and Well 2 each have three flow streams, oil, water, and gas.
  • the outlet of each multiport valve is connected to the inlet of each instrument.
  • each instrument When sampling begins, each instrument will analyze a sample from Well 1, then the multiport valve on the instrument will switch to Well 2 and analyze a sample.
  • Each instrument in the diagnostic platform is set up to run its own sampling sequence.
  • the sampling sequence consists of analysis time and flushing time. Flushing time is critical to ensure the sample lines from wells being sampled are fresh before each run.
  • the run times for the instruments can vary from two minutes up to one hour.
  • Each instrument in the platform is controlled by the computer. It executes three major processes: operation of the instrument, quantification of the tracers and transmission of the data.
  • the computer tells the multiplexing valve when to open and rotate, and when to activate the injection system. It quantifies the raw data from the system into time, date and concentration of the tracer or geochemical components. It then prepares the data to be sent over-the-air via the communications system.
  • the communications system takes the data in packets, encrypts them and transmits them via the internet to a receiving cloud computer or computer network.
  • each instrument produces a chromatogram, a time v. intensity plot, where the analytes appear as peaks. Each analyte is a different component or tracer chemical, and the area of its peak is proportional to its concentration.
  • the time v. intensity data of the chromatogram will be transferred to a cloud repository. These files will be uploaded to a time v. intensity plot for each sample and quality controlled by a data analyst. This is done for every sample each instrument analyzes.
  • the flow path of the reservoir fluid, the separation and the analysis, data processing, and results can be seen in Figure 9.
  • the last part of the diagnostic platform is the data delivery system which consists of time, date, and concentration outputs of the tracers or geochemical data from the instrument as well as well diagrams, field diagrams, formation diagrams, flowback schedules, production data, pressure data, and flowback data.
  • the system together enables engineers to make decisions and changes to their operations in real time and validates whether their changes are effective.
  • Figures 10, 11, and 12 show continuous reservoir data from the same well and time horizon for water tracer and water cation analysis, oil tracer and oil component analysis, and gas tracer and gas component analysis. Each of these figures comprises thousands of data points in the same time horizon.
  • Each component of the diagnostic platform is essential for continuously monitoring and optimizing reservoir performance.
  • the enclosed trailer, insulation, and heating and cooling system allows the instruments to be placed at field locations that are remote with harsh ambient conditions.
  • the satellite or cellular communication systems allows for transferring of large amounts of instrument data and continuous monitoring of the platform function.
  • the instruments analyze the fluids for specific components used to monitor the reservoir.
  • the sample lines carry the production fluids to the instrument, through the injection system and back to the production system or waste stream.
  • the multiport valves allow the system to switch between multiple wells as directed by the sampling sequence. Power to the diagnostic platform keeps its components running on a continuous basis.
  • the data delivery system summarizes the vast amount of data the platform produces into actionable data sets that engineers can use to optimize reservoir production.
  • a well operator ran the diagnostic platform to diagnose production from a section of a horizontal well that was drilled out of zone.
  • the horizontal well was three miles long in length and the toe portion of the lateral was drilled into rock above the intended target.
  • Three unique water and three unique gas tracers were injected into segments one mile long during fracturing stimulation.
  • the diagnostic platform was spotted ten feet from the separator and connected to the water, oil and gas lines. The platform was powered with utility power from the wellsite’ s production facility.
  • a multiport valve in the dead-end configuration was used for the gaschromatograph electron-capture detector for the gas tracers. It was connected to the well and a check sample. Analysis times were fourteen minutes with a twenty-minute flush time.
  • a multiport valve in the flow through configuration was used for the gas chromatograph thermal conductivity detector for the gas components, the liquid chromatograph UV-VIS for the water tracers and cations and the gas chromatograph flame ionization detector for the oil components.
  • the analysis time for the water tracers was twenty minutes with a five-minute flush time.
  • the analysis time for the water cations was twelve minutes with a five-minute flush time.
  • the analysis time for the gas components was five minutes with a five-minute flush time and the analysis time for the oil components was sixty minutes with a twenty-minute flush time.
  • compositions, methods, and devices are described in terms of “comprising” various components or steps (interpreted as meaning “including, but not limited to”), the compositions, methods, and devices can also “consist essentially of’ or “consist of’ the various components and steps, and such terminology should be interpreted as defining essentially closed-member groups. It will be further understood by those within the art that if a specific number of an introduced claim recitation is intended, such an intent will be explicitly recited in the claim, and in the absence of such recitation no such intent is present.
  • a range includes each individual member.
  • a group having 1-3 devices refers to groups having 1, 2, or 3 devices.
  • a group having 1-5 devices refers to groups having 1, 2, 3, 4, or 5 devices, and so forth.

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Abstract

L'invention concerne un appareil, un système, des compositions et un procédé pour observer un échantillon depuis un puits de forage traversant une formation souterraine comprenant la collecte continue d'un échantillon depuis le puits de forage, le dispositif de collecte comprenant un séparateur et une vanne, l'observation de l'échantillon dans un instrument pour caractériser l'échantillon, l'instrument étant enfermé dans un boîtier, le rapport d'un résultat de l'observation, et la régulation de la température du boîtier, de l'instrument, de l'échantillon, de la vanne, ou d'une combinaison de ceux-ci. L'invention concerne un appareil, un système, des compositions et un procédé pour observer un échantillon depuis un puits de forage traversant une formation souterraine comprenant un échantillon collecté en continu à partir du puits de forage, l'échantillon s'écoulant à travers un séparateur et une vanne, un instrument qui caractérise l'échantillon et enregistre les résultats de la caractérisation, l'instrument étant enfermé dans un boîtier, un dispositif de commande qui commande la température du boîtier, et un dispositif de rapport comprenant un système satellite ou un routeur cellulaire.
PCT/US2024/033495 2023-06-12 2024-06-12 Plate-forme de diagnostic directement reliée à une formation souterraine Ceased WO2024258899A1 (fr)

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
US202363472492P 2023-06-12 2023-06-12
US63/472,492 2023-06-12
US202363519169P 2023-08-11 2023-08-11
US63/519,169 2023-08-11
US202363595604P 2023-11-02 2023-11-02
US63/595,604 2023-11-02

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Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100132449A1 (en) * 2007-01-17 2010-06-03 Graham Birkett System and method for analysis of well fluid samples
US20110153225A1 (en) * 2008-01-25 2011-06-23 Schlumberger Technology Corporation In-line composition and volumetric analysis of vent gases and flooding of the annular space of flexible pipe
CN203455035U (zh) * 2013-09-18 2014-02-26 中国石油天然气集团公司 一种油田丛式井生产计量装置
US20150039233A1 (en) * 2010-09-10 2015-02-05 Selman And Associated, Ltd Method for near real time surface logging of a hydrocarbon or geothermal well using a mass spectrometer
WO2020139348A1 (fr) * 2018-12-27 2020-07-02 Halliburton Energy Services, Inc. Mesure de la concentration d'huile, d'eau et de solides dans des boues de forage à base d'huile

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100132449A1 (en) * 2007-01-17 2010-06-03 Graham Birkett System and method for analysis of well fluid samples
US20110153225A1 (en) * 2008-01-25 2011-06-23 Schlumberger Technology Corporation In-line composition and volumetric analysis of vent gases and flooding of the annular space of flexible pipe
US20150039233A1 (en) * 2010-09-10 2015-02-05 Selman And Associated, Ltd Method for near real time surface logging of a hydrocarbon or geothermal well using a mass spectrometer
CN203455035U (zh) * 2013-09-18 2014-02-26 中国石油天然气集团公司 一种油田丛式井生产计量装置
WO2020139348A1 (fr) * 2018-12-27 2020-07-02 Halliburton Energy Services, Inc. Mesure de la concentration d'huile, d'eau et de solides dans des boues de forage à base d'huile

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