WO2013060903A1 - Método para determinar en tiempo real la porosidad y la saturación de agua de una formación subterránea usando datos de registro de gas y de perforación - Google Patents
Método para determinar en tiempo real la porosidad y la saturación de agua de una formación subterránea usando datos de registro de gas y de perforación Download PDFInfo
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- WO2013060903A1 WO2013060903A1 PCT/ES2011/070734 ES2011070734W WO2013060903A1 WO 2013060903 A1 WO2013060903 A1 WO 2013060903A1 ES 2011070734 W ES2011070734 W ES 2011070734W WO 2013060903 A1 WO2013060903 A1 WO 2013060903A1
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- 238000005553 drilling Methods 0.000 title claims abstract description 116
- 238000000034 method Methods 0.000 title claims abstract description 70
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 52
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 42
- 238000004590 computer program Methods 0.000 claims abstract description 11
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 59
- 229930195733 hydrocarbon Natural products 0.000 claims description 26
- 150000002430 hydrocarbons Chemical class 0.000 claims description 26
- 230000035515 penetration Effects 0.000 claims description 21
- 239000004215 Carbon black (E152) Substances 0.000 claims description 18
- 238000012937 correction Methods 0.000 claims description 13
- 239000004927 clay Substances 0.000 claims description 4
- 238000010606 normalization Methods 0.000 claims description 2
- 239000007789 gas Substances 0.000 description 44
- 238000005755 formation reaction Methods 0.000 description 35
- 238000005259 measurement Methods 0.000 description 15
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- 238000011156 evaluation Methods 0.000 description 12
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- 238000012360 testing method Methods 0.000 description 7
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- 238000012512 characterization method Methods 0.000 description 3
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- 238000003908 quality control method Methods 0.000 description 3
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- 230000006399 behavior Effects 0.000 description 2
- 238000004364 calculation method Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000005251 gamma ray Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000012549 training Methods 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
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- 238000002290 gas chromatography-mass spectrometry Methods 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- -1 methane (C1) Chemical class 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
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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
- E21B49/003—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 by analysing drilling variables or conditions
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
- G01V1/44—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
- G01V1/48—Processing data
- G01V1/50—Analysing data
Definitions
- the present invention relates to the field of determining the fluid content of underground formations. More specifically, the invention relates to a method and a computer program product for determining the porosity (PHI) and water saturation (Sw) of an underground formation while drilling using gas registration and drilling data.
- PHI porosity
- Sw water saturation
- the volume fraction of pores occupied by water (hereinafter referred to as "water saturation” and represented by Sw) is a key fact in the early evaluation of fluid formation and characterization. It is assumed that the pore space not occupied by water contains oil and / or gas.
- a, n and m are empirically determined factors that relate porosity to the resistivity of porous rock formation when fully saturated with water.
- E-logs After drilling, in addition to using gamma ray, electrical resistivity and neutron test tools, one or more measurement tools are introduced into the perforation and their responses are recorded against various lithologies. These tests are often collectively referred to as E-logs.
- the E-logs themselves may be indicative of the porosity of lithology and water saturation. Therefore, the E-logs are used after drilling, to determine if a formation is porous and contains hydrocarbon. For economic reasons, it is important to determine in real time, that is, while drilling, what is the fraction of pore volume of the perforated formations that is occupied by oil and / or gas, prior to the use of the cable survey tool or to plan the future course of action.
- the drilling log is a mobile laboratory provided by the drilling logging company, located near the drill tower to track, control and record all drilling and geological information.
- the drilling record includes the observation and microscopic examination of the drilling detritus (rock formation flakes), and the evaluation of gaseous hydrocarbons and their
- Drill Penetration Rate (sometimes referred to as the drilling rate)
- Pumping Rate (amount of fluid being pumped)
- Pressure Pumping (WOB)
- Column Weight (weight of the drilling fluid)
- Drilling, Rotation Speed, Rotary Torque, Revolutions Per Minute (RPM), Emboladas Per Minute (SPM), Mud Volumes, Sludge Weight and Sludge Viscosity While drilling, the gas released from a sludge returning from the well to the gas trap can be analyzed using real-time sensors that measure at a specified sampling rate the amount of hydrocarbons (particularly methane (C1), ethane ( C2), etc.) in ppm (parts per million). These measurements can be used as an indication of the presence of hydrocarbons in the formation at various depths.
- the invention described herein refers to a method for using the gas and drilling log data obtained while drilling in a quantitative manner to determine the saturation of water in the formation and its porosity.
- a method is provided to determine water saturation (Sw_Gas) and porosity ( ⁇ , "PHI", which is porosity in general, and when obtained using the methodology described in the present invention: in case of that E-logs of a reference well are available is called PHI_LOG and when E-logs of a reference well is not available, it is called PHMVIL) of an underground formation while drilling from the registration data of gas and drilling that are obtained while drilling.
- a first aspect of the present invention relates to a method for determining the porosity (PHMVIL and / or PHI_LOG) and water saturation (Sw_Gas) of an underground formation while drilling, comprising:
- Pl Perforability Index
- ROP normalized Penetration Rate
- V. determine the value of Sw_Gas from the baseline of Gw obtained in stage IV and determine the porosity using the E-log data of a reference well (PHI_LOG) or from the Ploi ⁇ ne obtained in stage IV when a reference well (PHMVIL) is not available.
- Another aspect of the invention relates to a computer program product comprising program instructions for having a computer perform the method for determining the porosity and saturation of water while drilling as defined above.
- Said computer program can be incorporated in storage media (for example, in a recording medium, in a computer memory or in a read-only memory), or supported on a carrier signal, for example, to be downloaded from a computer or sent by email (for example, in an electrical or optical carrier signal).
- Another aspect of the invention relates to a system for determining the porosity (PHI) and water saturation (Sw) of an underground formation while drilling, the system being characterized in that it comprises computer means for calculating the Perforability index.
- Pl the inverse of the normalized Penetration Rate (ROP) that is solved as the mathematical correction of the drilling record parameters obtained while drilling that affects the ROP, using data from the drilling record Penetration (ROP), Revolutions per Minute (RPM) and Force on the Drill (WOB) obtained while drilling
- computer means for normalizing methane (C1) data as the mathematical correction for the variation of drilling parameters
- this aspect of the invention can be formulated as a system for determining the porosity (PHI) and water saturation (Sw) of an underground formation while drilling, the system comprising a memory and a processor, which incorporate instructions stored in the memory and executable by the processor, including the instructions functionality for:
- Pl Perforability Index
- ROP normalized Penetration Rate
- the described system can be part (for example, hardware in the form of a PCI card) of a computer system (for example a personal computer).
- the system can be external hardware connected to the computer system by appropriate means.
- Figure 1 C1 normalized versus depth. This graph shows the evolution of methane with depth.
- Figure 2 C1 normalized versus resistivity.
- Figure 3 Perforability index (Pl) versus depth.
- BT chart Pl versus C1 normalized. It consists of a double logarithmic graph (log log cross graph) of a standard C1 (in ppm) on the Y axis versus the Perforability index on the X axis.
- Ploiine- Figure 6 PHINDX by (Density / Neutron) versus Perforability index (Pl) with RMA line (Reduced Major Axis).
- the RMA line is defined when the line fit provides an equation that is halfway between a linear and polynomial regression method. RMA allows a reliable line fit when conventional regression methods cannot.
- FIG. 7 Comparison of Sw and porosity obtained by the method of the invention against Sw and PHI obtained by E-log for the entire well.
- Drilling Record (“Mud Logging”, ML): is a mobile laboratory located by the drilling log company near the derrick to track, control and record all geological and drilling.
- Rotary Speed (“Revolutions Per Minute”, RPM): defined as the speed at which the drill is rotated during drilling operations and measured in revolutions per minute (rpm).
- Force on the Drill Bit (WOB): is the amount of force down (on the drill bit) exerted on the drill bit and is usually measured in thousands of pounds or thousands from
- Penetration Rate is the speed at which a drill bit breaks the rock to deepen the drilling. It is also known as penetration rate or perforation rate. It is usually measured in feet per minute or meters per hour, but sometimes it is expressed in minutes per foot.
- Flow is the amount of mud pumped into the well. It is usually measured in gpm (gallon per minute) or liter per minute.
- Bit Size (“Bit Size", BS): the diameter of the hole.
- Drilling Exponent is a method to normalize the ROP for changes in WOB, RPM and Drill Size (BS).
- Normalized Gas is the mathematical treatment of the parameters that affect the measurement of gas (mainly FLOW, ROP, BS).
- Methane (C1) is the simplest alkane, and the main component of natural gas.
- Gas Measurement it is a gas reading that varies in magnitude or composition in front of the possible hydrocarbon zone.
- Gamma rays (“Gamma Ray", GR): The gamma ray log is a method of measuring the natural appearance of gamma radiation to characterize rock or sediment in a hole.
- MWD (for its acronym in “Measurement While Drill ing") represents the measurement while drilling in the oil industry. It is a system created to perform measurements related to drilling, within it, and transmit information to the surface while drilling a well.
- the MWD tools are transported to the bottom of the well as part of the bottomhole rig ("Bottom Hole Assembly", BHA).
- BHA Bottom Hole Assembly
- the tools are contained within the drill collar (probe type) or are built into the collars themselves.
- Logging While Drilling is a technique for transporting logging tools from the well into the bottom of the borehole as part of the bottom rig well (BHA).
- GWD (for its acronym in English "Gas While Drill ing") represents gas while drilling in the oil industry. It is a methodology to interpret gas data in terms of fluid characterization.
- WLFT (for its acronym in English “Wire Line Formation Tester”, WLFT) represents the test apparatus of the Cable Formation and measures the pressure of the formation and is capable of recovering fluid samples after drilling the well.
- Sample from the bottom of the WL well it is a sample of fluid obtained by WLFT.
- DST (for its acronym in English "Drill Steam Test"): represents the Steam test of the Well. It is a temporary conclusion whereby the desired section of the open well is isolated and released from the pressure of the drill column through the drill pipe.
- WL (for its acronym in “Wire Line”, WL) represents the cable survey. It is a practice to make a detailed record of the geological formations drilled in a hole.
- OWC (for its acronym in “Oil-Water Contact”, OWC): represents the Oil-Water Contact. It is the limit between two fluids.
- QC Quality Control
- PHINDX or PHI Density / Neutron: Porosity obtained by density / neutron registration recorded by cable tool.
- Rt real resistivity of the formation.
- RMA Reduced Major Axis Line
- Porosity is the empty space in the rock that contains fluids. It is measured in terms of the volume of empty space of the total volume of the rock. In the described methodology, it is expressed as one. Therefore, if a rock has a PHI value of 0.2 it means that it has 20% free space to hold fluid.
- Water saturation (Sw) of the rock is the volume fraction of pores occupied by water. In the described methodology, it is expressed as one. Therefore, if a rock has a Sw value of 0.3 it means that 30% of its pore space (PHI) is occupied by water and the remaining 70% is occupied by hydrocarbon.
- a minimum series of resistivity data, porosity registers and GR is required for the evaluation of a formation in a scenario where cable probing is used.
- these direct physical measurements have been replaced by drilling and gas data, particularly Methane (C1), and ROP ( Penetration rate).
- Methane (C1) has been selected as a substitute for the resistivity curve, and a normalized ROP function as a substitute for porosity records.
- the GR necessary as a lithology discriminator, is usually recorded while drilling. If GR is not available, the description of detritus can be used as an indicator of lithology.
- high gas measurements correspond to the presence of hydrocarbons (a high or higher resistivity with respect to the formation water) and, a low gas measurement is recorded, mainly in the presence of an area that carries water or an area of clays, which is characterized by low resistivity.
- the method of the present invention uses the inverse of the normalized Penetration Rate (ROP) obtained while drilling, which is called the Perforability Index (Pl), as an indicator of porosity.
- ROI Perforability Index
- variations in the Penetration Rate (ROP) are generally associated with porosity and lithology. Normally, low ROP values are recorded, in particular in compact lithologies (low porosity), while high ROP is generally recorded in the presence of porous areas.
- Methane (C1) is normally recorded in:
- ROP Penetration Rate
- the calculation of Sw, by gas, according to the method of the present invention can be performed without "calibration or reference wells" and / or existing interpretation models.
- the Perforability Index (Pl) is calculated from equation 1 (Eq. 1):
- the normalization of C1 is the mathematical correction of the parameters that affect the measurement of gas, such as ROP, FLOW and BS, and is the only technique capable of analyzing and correcting the gas data of different drilling phases and different wells .
- the step of normalizing the C1 data is calculated from equation 2 (Eq. 2):
- Equation 2 takes into account only the drilling surface parameters obtained while drilling.
- Stage III of the method consists of the representation of normalized C1 versus Pl in a double logarithmic graph (cross log log graph) (see Figure 4).
- the graph is called BT (Beda & Tiwary) and consists of a double logarithmic graph of C1 (in ppm) on the Y axis versus the Perforability index (Pl) on the X axis.
- the graph is used to obtain the baseline of Gw that represents 100% of Sw. On this graph (see Figure 4) you can see two groups of points.
- Group 1 (grupol in Figure 4)) that have lower C1 values refers to formations containing water and clay formations, while group 2 (group2 in Figure 4) at the top of the graph, which have C1 values higher, refers to formations containing hydrocarbon with different saturation values.
- the Gw line is drawn as a straight line that passes through the upper part of group 1.
- the Gw line represents a schematic division of the previous graph into two parts.
- the points below the Gw line represent points with 100% water saturation. While the points above the Gw line represent points with saturation below 100% depending on their position with respect to the Gw line, which means that they have saturation with hydrocarbon.
- the baseline of Gw is a straight line that passes through the upper data points of the clay and water zone in the double logarithmic plot of the data of C1 normalized against the Perforability index (Pl).
- the water / clays zone is defined by the baseline of Gw.
- the points below the Gw line will have 100% Sw while the points above the baseline should have a lower Sw value.
- the baseline has to be drawn in the cloud of upper points below the scattered points at the top of the graph.
- the slope of the baseline is directed by the points to the right of the graph with high values of Pl and low values of C1 normalized. All points above this line (high C1 values) will have a Sw value of less than 100%.
- the determination of water saturation (Sw_Gas) using the baseline stage of Gw comprises solving equation 3 (Eq. 3)
- Gh are the points of normalized C1 (ppm) at each point of drilling depth. On the Gw line, the value of Gw is equal to Gh.
- the drilling record data obtained on the surface are essentially dependent on lithology and porosity. While drilling is performed, lithology is known by detritus, GR / MWD or by reference wells, and the main unknown variable remains porosity. This approach, without significant variations in the
- the objective is to have a porosity profile in real time, which is comparable in terms of trend and magnitude to the porosity obtained by E-logs, to better understand the properties of the reservoir, to predict the net thickness and optimize the acquisition of records and testing.
- the method of the present invention for determining the porosity of an underground formation while drilling, it can be applied both when a calibration or reference well is available (i.e., when a complete series of E-logs) as when any calibration record is lacking.
- the porosity (PHI_Log) is calculated by obtaining the relationship between the porosity ( ⁇ , "PHI") and the Perforability index (Pl) representing on a linear scale the Pl ( on the X axis) versus Total Porosity (on the Y axis) obtained from the E-log data in the calibration well.
- the calculation of the PHI_Log is obtained using the RMA line and the RMA regression formula obtained by the
- the PHI_Log is calculated using the RMA regression formula obtained by the previously defined graph.
- the porosity in the deposit shows several large changes that are difficult to estimate by this methodology. Although an accurate prediction of porosity is not obtained, the average estimate should be considered good. The trend and magnitude of the expected porosity are in line (typical error +/- 10%) with the porosity obtained from the registry.
- PHMvIL porosity
- Ploiine baseline of Pl in the shale area or zone with porosity of 0%
- K and M are calculated by correlation of Pl with the porosity obtained by registration, they could vary with the lithology and basin and
- the embodiments of the invention comprise processes performed on computer devices
- the invention also includes the computer apparatus and computer programs, particularly computer programs on a support, adapted to practice the invention.
- a computer program product comprising program instructions for making a computer carry out the method of determining porosity (PHI) and also part of the invention.
- PHI porosity
- Sw Water saturation
- the program may be in the form of source code, object code, source code and an intermediate object code, such as in partially compiled form, or in any other form suitable for use in carrying out the processes according to the invention.
- the computer program product is incorporated into a storage medium.
- the software product is supported on a carrier signal.
- the support can be any entity or device capable of supporting the program.
- the support may comprise a storage medium, such as a ROM, for example, a CD ROM or a semiconductor ROM, or a magnetic recording medium, for example a flexible disk or a hard disk.
- a storage medium such as a ROM, for example, a CD ROM or a semiconductor ROM, or a magnetic recording medium, for example a flexible disk or a hard disk.
- the support can be a transmissible support such as an electrical or optical signal, which can be transported by electrical or optical cable or by radio or other means.
- the support can be constituted by said cable or other device or means.
- the support can be an integrated circuit in which the program is incorporated, the integrated circuit being adapted to perform, or to be used in performing the relevant process.
- the methodology of the present invention is carried out while drilling exploratory wells, and is more efficient and reliable for evaluation / development wells.
- the measurement of the porosity and saturation of water obtained while drilling is carried out by the method described above allows to deduce the volume of hydrocarbon, that is, the total volume of oil and / or gas contained in a given reservoir, and reduce the intrinsic uncertainty to the petrophysical interpretation of E-logs.
- T (l - Sw) PHIVt in which T is the Total amount of hydrocarbon, Sw and PHI are the saturation of water and the porosity taken in the entire reservoir, and Vt is the total volume of the reservoir.
- this evaluation is usually done layer by layer, that is, by adding the hydrocarbon volumes that correspond to various areas in the reservoir.
- the innovative methodologies of the present invention allow an early evaluation of possible hydrocarbon intervals and an early estimation of the Sw and total porosity. In this way, this method will allow a preliminary evaluation of the deposit at the well site.
- the method of estimating water saturation (Sw_Gas) and porosity (PHMVIL) in real time of the present invention will help to solve the ambiguity of petrophysical interpretation in low situations
- the case study presented in this document corresponds to a well located in a shallow water environment, offshore.
- the sedimentology sequence consists of carbonate deposits from
- the calibration was done by drawing the RMA line and calculating the equation between Pl and the porosity derived from the petrophysical analysis of the cable survey data. Once the equation is known, porosity can be predicted using real-time Pl while drilling (since Pl will be available in real time during drilling).
- the first stage of the process is the validation of the data series by performing a severe quality control using the well-known GWD methodology and the QC methodology performed by the Service Co.
- useful graphics have to be prepared in advance to demonstrate reproducibility and reliability of the data.
- the graph shows the good correspondence between Methane (C1) and Resistivity.
- the good relationship between the resistivity and C1 confirms that the use of C1 to replace the resistivity curve for the evaluation of gas formation allows the prediction of the main reservoir parameters (Sw and PHI).
- the Pl Perforability index
- This parameter is directly related to changes in
- the gas data (Methane, C1) and ROP were normalized to calculate the normalized C1 and the Perforability index (Pl).
- the normalized C1 data plot versus Pl was constructed on a double logarithmic graph (log log cross graph) ( Figure 4).
- the graph was used to derive the baseline Gw representing 100% Sw.
- Group 1 grupol in Figure 4
- group 2 group2 in Figure 4
- the Gw line was drawn as a straight line that passes through the upper part of group 1.
- the Gw line represents a schematic division of the previous graph into two parts.
- the points below the Gw line represent points with 100% water saturation. While the points above the Gw line represent points with saturation below 100% depending on their position with respect to the line, which means that they have saturation with hydrocarbon.
- the equation of this baseline of Gw is:
- the second parameter of the deposit obtained by the invention is Porosity.
- the first porosity curve is obtained without the use of a calibration well by applying equation 4 (Eq. 4).
- the vital parameter equation 4 is Ploi ⁇ ne, you obtained using the cross graphic Depth axis X and Pl Y axis, both in a linear scale (see Figure 5).
- the baseline Ploime is drawn by passing a straight line through the group of points that have lower Pl values in the Pl plot versus depth.
- the equation for this line, Ploime, for the well described in the present example is the following.
- Another method to obtain the porosity curve is to use well log data for calibration. This method can only be used when they are curves of well registration porosity present in the well. Once the PHI_LOG value has been obtained by calibration, it can then be used in real time with the same calibration coefficient for future wells in the basin.
- the graph in Figure 6 is a cross plot of Pl on the X axis and Porosity by Density / Neutron on the Y axis, both on a linear scale.
- the graph shows the relationship between the value of Pl and Porosity by Density / Neutron (recorded by the cable survey at the end of the drilling phase).
- the RMA regression line is drawn between the two variables as shown in Figure 6.
- the PHI_LOG can be obtained for any well that is in the same basin.
- Fig. 7 shows the comparison between the parameters (Sw_Gas, PHMVIL & PHI_LOG) obtained by the methodology of the invention in real time and the same parameters obtained by the petrophysical analysis of the cable probing recorded at the end of the drilling phase.
- Sw_Gas and Sw_Elog are represented together. The two curves follow in trend and magnitude. The small difference between the two values is within the tolerance limit of + -10%.
- the second section shows the PHI_LOG and PHINDX curves (Porosity obtained by Density / Neutron registration). The two curves again follow in trend and magnitude.
- the third section shows the PHMVIL curves represented together with PHINDX.
- the PHMVIL can replicate the behavior of PHINDX in both trend and magnitude.
- the PHMVIL when obtained without any well of Calibration, may not have a good correlation with the PHINDX, but provides an approximate porosity profile, similar to PHINDX, which is an essential parameter to assess the quality of the deposit during the drilling operation.
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Abstract
Description
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Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
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MX2014004885A MX2014004885A (es) | 2011-10-24 | 2011-10-24 | Metodo para determinar en tiempo real la porosidad y la saturacion de agua de una formacion subterranea usando datos de registro de gas y perforacion. |
US14/353,773 US20140379265A1 (en) | 2011-10-24 | 2011-10-24 | Real-time method for determining the porosity and water saturation of an underground formation using gas and mud logging data |
EP11805066.5A EP2772775A1 (en) | 2011-10-24 | 2011-10-24 | Method for determining in real time the porosity and water saturation of an underground formation using gas level and drilling data |
PCT/ES2011/070734 WO2013060903A1 (es) | 2011-10-24 | 2011-10-24 | Método para determinar en tiempo real la porosidad y la saturación de agua de una formación subterránea usando datos de registro de gas y de perforación |
AU2011379934A AU2011379934A1 (en) | 2011-10-24 | 2011-10-24 | Method for determining in real time the porosity and water saturation of an underground formation using gas level and drilling data |
BR112014009813A BR112014009813A2 (pt) | 2011-10-24 | 2011-10-24 | processo em tempo real para determinação de porosidade e saturação com água de uma formação subterrânea usando dados de transporte de lama e gás |
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PCT/ES2011/070734 WO2013060903A1 (es) | 2011-10-24 | 2011-10-24 | Método para determinar en tiempo real la porosidad y la saturación de agua de una formación subterránea usando datos de registro de gas y de perforación |
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WO2013060903A1 true WO2013060903A1 (es) | 2013-05-02 |
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PCT/ES2011/070734 WO2013060903A1 (es) | 2011-10-24 | 2011-10-24 | Método para determinar en tiempo real la porosidad y la saturación de agua de una formación subterránea usando datos de registro de gas y de perforación |
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US (1) | US20140379265A1 (es) |
EP (1) | EP2772775A1 (es) |
AU (1) | AU2011379934A1 (es) |
BR (1) | BR112014009813A2 (es) |
MX (1) | MX2014004885A (es) |
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US11512580B2 (en) | 2020-05-11 | 2022-11-29 | Saudi Arabian Oil Company | Real-time estimation of reservoir porosity from mud gas data |
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US11668847B2 (en) | 2021-01-04 | 2023-06-06 | Saudi Arabian Oil Company | Generating synthetic geological formation images based on rock fragment images |
US20220268152A1 (en) * | 2021-02-22 | 2022-08-25 | Saudi Arabian Oil Company | Petro-physical property prediction |
US12055015B2 (en) * | 2021-03-24 | 2024-08-06 | Halliburton Energy Services, Inc. | Drilling system with gas detection system for use in drilling a well |
CN113719280A (zh) * | 2021-09-08 | 2021-11-30 | 陕西能源职业技术学院 | 一种低阻气层测井识别方法 |
CN117266843B (zh) * | 2023-09-27 | 2024-03-26 | 广东海洋大学 | 油藏水淹层识别方法、系统、装置及存储介质 |
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- 2011-10-24 BR BR112014009813A patent/BR112014009813A2/pt not_active IP Right Cessation
- 2011-10-24 WO PCT/ES2011/070734 patent/WO2013060903A1/es active Application Filing
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EP2772775A1 (en) | 2014-09-03 |
BR112014009813A2 (pt) | 2017-04-18 |
US20140379265A1 (en) | 2014-12-25 |
MX2014004885A (es) | 2014-10-17 |
AU2011379934A1 (en) | 2014-06-12 |
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