WO2003098266A1 - Formation testing while drilling data compression - Google Patents
Formation testing while drilling data compression Download PDFInfo
- Publication number
- WO2003098266A1 WO2003098266A1 PCT/US2003/015921 US0315921W WO03098266A1 WO 2003098266 A1 WO2003098266 A1 WO 2003098266A1 US 0315921 W US0315921 W US 0315921W WO 03098266 A1 WO03098266 A1 WO 03098266A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- pressure
- formation
- curve fit
- data
- curve
- Prior art date
Links
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
- G01V11/002—Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
- E21B47/18—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid, e.g. mud pressure pulse telemetry
-
- 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
Definitions
- the present invention generally relates to methods and apparatus for using a formation tester to retrieve formation characteristics on a subterranean formation through a wellbore by acquiring pressure versus time response data in order to calculate formation pressure, permeability, and other formation characteristics. More particularly, the present invention relates to a method of acquiring said data from a formation tester disposed in a drill string configured to perform formation testing while drilling operations. More particularly still, the present invention relates to a method of compressing the amount of data transmitted to the surface during a formation testing while drilling operation to decrease the amount of time required to transmit the formation characteristic data.
- hydrocarbons are stored in subterranean formations. Hydrocarbons are not typically located in large underground pools, but are instead found within very small holes, or pore spaces, within certain types of rock. The ability of a rock formation to allow hydrocarbons to move between the pores, and consequently into a wellbore, is known as permeability. The viscosity of the oil is also an important parameter, and the permeability divided by the viscosity is termed "mobility" (k/ ⁇ ). Similarly, the hydrocarbons contained within these formations are usually under pressure and it is important to determine the magnitude of that pressure in order to safely and efficiently produce the well.
- a wellbore is typically filled with a drilling fluid ("mud"), such as water, or a water-based or oil-based mud.
- mud drilling fluid
- the density of the drilling fluid can be increased by adding special solids that are suspended in the mud. Increasing the density of the drilling fluid increases the hydrostatic pressure that helps maintain the integrity of the wellbore and prevents unwanted formation fluids from entering the wellbore.
- the drilling fluid is continuously circulated during drilling operations. Over time, as some of the liquid portion of the mud flows into the formation, solids in the mud are deposited on the inner wall of the wellbore to form a mudcake.
- the mudcake acts as a membrane between the wellbore, which is filled with drilling fluid, and the hydrocarbon formation.
- the mudcake also limits the migration of drilling fluids from the area of high hydrostatic pressure in the wellbore to the relatively low-pressure formation. Mudcakes typically range from about 0.25 to 0.5 inch thick, and polymeric mudcakes are often about 0.1 inch thick. On the formation side of the mudcake, the pressure gradually decreases to equalize with the pressure of the surrounding formation.
- a formation tester 500 is lowered on a wireline cable 501 to a desired depth within a wellbore 502.
- the wellbore 502 is filled with mud 504, and the wall of the wellbore 502 is coated with a mudcake 506. Because the inside of the tool is open to the well, hydrostatic pressure inside and outside the tool are equal.
- a probe 512 is extended to sealingly engage the wall of the wellbore 502 and the tester flow line 519 is isolated from the wellbore 502 by closing equalizer valve 514.
- FTWD formation testing while drilling
- FTWD tools disposed on drill strings do not generally include transmission paths for transmitting data to and receiving data from the surface.
- Communication links such as data cables, fiber optic cables, or RF transceivers are simply not present in conventional drill strings.
- This problem is not new in the art. It has long been recognized in the oil and gas industry that communicating between the surface equipment and the subsurface drilling assembly is both desirable and necessary. Uplink and downlink signaling, or communicating between surface equipment and a drilling assembly, is typically performed to provide instructions in the form of commands to the drilling assembly and for transmitting logging data to the surface.
- downlink signals may instruct the drilling apparatus to alter the direction of the drill bit by a particular angle or to change the direction of the tool face.
- Uplink signaling, or communicating between the drilling assembly and the surface equipment, is typically performed to verify the downlink instructions and to communicate data measured downhole during drilling to provide valuable information to the drilling operator.
- a common method of downlink signaling is through mud pulse telemetry.
- Mud pulse telemetry is a method of sending signals by creating a series of momentary pressure changes, or pulses, in the drilling fluid, which can be detected by a receiver.
- the pattern of pressure pulses including the pulse duration, amplitude, and time between pulses, is detected by the downhole receiver and then interpreted as a particular instruction to the downhole assembly.
- mud pulse telemetry as a communication means is well known to those skilled in the art.
- Representative examples of mud pulse telemetry systems may be found in U.S. Patent Nos. 3,949,354, 3,958,217, 4,216,536, 4,401,134, 4,515,225 and 5,113,379.
- An unfortunate limitation to mud pulse telemetry systems is that bandwidth is severely limited as compared to wireline data transmission systems. It is generally accepted by those skilled in the art that data transmission rates in mud pulse telemetry systems are on the order of about two bits per second.
- the size of the digital words that represent each individual sample must be kept small enough and the time between samples must be kept far enough apart to allow the data to be transmitted real time. In general, these limitations are in contrast with the requirements for reconstructing a curve from digital samples. It is normally desirable to include samples with larger bit resolutions that are spaced close enough to each other to guarantee that all relevant pressure characteristics are transmitted uplink. Unfortunately, mud-pulse telemetry simply does not afford this luxury. With the two bit/second limitation, eight-bit word pressure samples may be transmitted no faster than every four seconds. In reality, bit resolutions must be even smaller and sample rates must be larger to account for packet headers and other transmission data.
- Figure 2 shows a typical formation pressure test curve and related events
- Figure 3 shows a schematic representation of a formation test while drilling (FTWD) tool in a downhole configuration adapted to transmit compressed formation pressure test curve data in accordance with the preferred embodiment
- Figures 4A and 4B show representative formation pressure test curves reflecting different formation characteristics
- Figure 5 shows a formation pressure test curve reflecting the time and curve fit parameter dependence for the time varying portions of the curve
- Figure 6 shows a formation pressure test curve reflecting the critical time variables that are considered in generating the compressed formation test curve data.
- the preferred embodiment is implemented in conjunction with a formation test while drilling (FTWD) apparatus 30 of the type shown in Figure 3.
- the FTWD apparatus 30 is preferably disposed along a drill string 32, which may be comprised of segmented portions or may be embodied as a continuous length of coiled tubing.
- the FTWD apparatus 30 includes any relevant mechanical, hydraulic, and electrical components that may be found in an equivalent wireline formation tester. For clarity, only the formation pressure probe 33, flowline 34, and a drawdown fluid chamber 35 are shown in the FTWD apparatus 30 of Figure 3.
- a formation test is initiated by engaging a packer pad or pads 38 against the wall of the wellbore 40.
- a pretest or drawdown piston retracts to draw formation fluid from the probe 33 into the flowline 34 at a rate that is faster than the rate at which formation can flow out of the formation.
- This drawdown process creates an initial pressure drop within the flowline 34 and chamber 35.
- pressure in the flowline 34 and chamber 35 gradually increases until the pressure equalizes with the formation pressure.
- the formation pressure and pressure values that appear during initial packer set, drawdown, and buildup, as well as before and after the formation test are all measured with a pressure transducer 36 that is mounted in chamber 35 or in a position that permits detection of pressures in flowline 34 or chamber 35.
- control module 45 also stores instructions (in memory 47) in the form of a script language or other software code that allows processor 46 to perform the compression of all pressure readings transmitted from transducer 36.
- the control module 45 preferably stores the data samples in storage 48 until the formation test is complete or until a sufficient number of samples have been acquired, at which point the processor analyzes the pressure samples and performs a curve fit analysis to the samples.
- the control module 45 may process pressure sample data in pseudo-real time to transmit compressed data values to the surface as they are generated. A more detailed description of the curve fit analysis and parameters is provided below.
- Figures 4A and 4B two representative formation pressure test curves are shown. The curves resemble, but do not exactly match the representative curve shown in Figure 2.
- the formation tests performed in each of the two curves were conducted with different formation fluid characteristics.
- the curves represent the reconstruction of a formation test pressure curve using the compressed data points and curve fit parameters in accordance with the preferred embodiment. In any event, it is still readily discernible from the curves in Figures 4A and 4B that formation fluid and pressure characteristics have a marked effect on the shape and values exhibited by the test curves.
- the formation test was performed with a fluid mobility that is roughly two orders of magnitude lower than the fluid mobility in Figure 4B. More mobile fluids generally tend to flow more readily and, consequently, pressures tend to stabilize more quickly for a more mobile fluid. In other words, more mobile fluids react to transients more readily than do less mobile fluids.
- This characteristic is apparent in the drawdown curves 50, 52 as well as the buildup curves 54, 56 in Figures 4A and 4B.
- the drawdown cycle 50 is characterized by a more gradual slope downward to the point at which the buildup curve begins.
- the formation pressure 55 is reached after a much longer period of time than that shown in Figure 4B. Again, this reflects the ability of the formation fluid to react to the pressure transient created within the FTWD apparatus 30. Given that different formation test curve shapes may be expected with different formation characteristics, it is possible to develop curve fit parameters that permit reconstruction of the formation test curves and, consequently, represent formation fluid characteristics. If one assumes that the drawdown and buildup curves may be represented by logarithmic functions, then the curves may be expressed in terms of the general equation
- Parameters a and ⁇ may be generated using one or both of the equations Pdd or Pbu. If one equation is used, it is preferred that equation Pbu be used. If both equations are used, the parameters and ⁇ will be substantially the same such that either pair of values may be used, or some average or correlation of the two pair of values may be used.
- ⁇ and P f are generated, the approximated solutions to Pdd and Pbu may then be compared to the actual pressure samples to generate some measure of the correlation.
- a Chi-squared (X 2 ) value is generated and transmitted as a measure of this correlation. Calculation of this X 2 value is discussed below and provided in Appendix C. It should be noted that this particular error function is chosen because the result is bounded and provides a quantitative value for the quality of the resultant curve fit generated by the control module 45. It is entirely feasible that other error functions known to those in the art can just as easily be applied to the present curve fit analysis.
- the information transmitted from the control module 45 to the surface include a limited number of actual data points, the curve fit parameters , ⁇ and Pf, and the X 2 correlation figure. It is envisioned that at least five specific data points shown in Figures 4A and 4B should be transmitted as part of the preferred solution. These points include: Phydi, Pdd, Pfu, Pstop, and Phyd2.
- Phydi represents the hydrostatic pressure sampled in the FTWD apparatus 30 prior to extension of the packer 38 and closing of the equalizer valve, such as the equalizer valve 514 found in the wireline formation tester of Figure 1.
- Pdd represents a pressure sampled following the packer 38 extension and set.
- P& represents the pressure within the FTWD apparatus 30 following the drawdown cycle and before pressure begins to increase to the formation pressure.
- Pstop represents the final pressure measurement taken before the packer 38 is released and the equalizer valve is opened, thereby coupling the flowline 34 and fluid chamber 35 to hydrostatic and annulus pressures Phyd2.
- control module 45 may terminate the formation test and transmit all relevant data points, curve fit parameters, and the data points leading up to the final formation pressure sample P(n).
- some predetermined threshold perhaps say 1 psi or some percentage
- the control module 45 may terminate the formation test and transmit all relevant data points, curve fit parameters, and the data points leading up to the final formation pressure sample P(n).
- a drilling operator may use the data samples and curve fit parameters to judge whether successful results were achieved.
- This early termination may be executed by the control module regardless of whether the pumps are on during the formation test.
- the pumps-on scenario provides some additional advantages.
- time variables are shown in Figure 6 as ⁇ thydri, ⁇ thydr2, ⁇ tset, and ⁇ tpd.
- ⁇ thydri and thydr2 represent the initial and final hydrostatic wait times, respectively.
- ⁇ tset represents the packer setting time
- ⁇ tpd represents the pressure data time spacing.
- each of the time variables are set to a default value at the surface and should correspond to time sequence settings within the FTWD apparatus 30. Whenever possible, data samples should be taken to coincide with control commands or events that initiate FTWD apparatus 30 functions.
- the hydrostatic pressure can be measured after a set time period. Then, after the equalization valve is closed and the packer is extended, the tool is ready for the pretest or drawdown piston to be activated. Immediately before the piston is activated, the Pdd and tdd values should be recorded. Further, the P& and tfu values are preferably measured when the pretest piston stops moving. It may be the case that the pretest piston does not reach a final position so as to trigger a limit switch. In this case, Pfu and tfu can simply be sampled after a fixed amount of time or based on the slope of the drawdown curve. Those sldlled in the art will certainly recognize a variety of solutions for determining the proper termination of the drawdown and initiation of the buildup cycles.
- Table 1 summarizes the events alluded to above and indicates suitable times when the critical data points and time variables should be selected.
- the control module 45 preferably receives data samples on a regular basis from the transducer 36. The control module stores these data points for use in generating curve fit parameters, but the events below should preferably be used to identify the critical data points, perhaps so the control module 45 can store the data points in a separate location in memory. Redundant copies of these data points may be made so that they can be used in calculating the curve fit parameters as well as transmitted to the surface once the formation test completes.
- the minimal five-point data set, the two time variables and four curve fit parameters, with the bit resolution and ranges shown in Table 2 are combined to form a 116-bit data set.
- the size of the packet in which this data is transmitted will be nominally larger, but at a two bits/second transmission rate, the minimal data set can be transmitted uplink in just over 58 seconds.
- This minimal data set does not include any additional P(i) data points.
- an extra five points for example, requires an extra 60 bits to be transmitted uplinlc.
- the additional data points will require at least an extra 30 seconds to upload.
- the formation pressure test curve may be reconstructed by plotting a horizontal hydrostatic pressure line representing Phydrl for the initial hydrostatic wait time ⁇ thydri. At the end of ⁇ thydri, a vertical line is plotted from Phydrl to Pdd. Again, a horizontal line is plotted for the duration of ⁇ tset and ending with the Pdd pressure point at tdd.
- the time varying plots for Pdd(t) and Pbu(t) are then drawn according to the equations shown in Appendix A. Pdd(t) is plotted with t beginning at 0 (starting at tdd) and ending at tfu ( ⁇ tdd total).
- Pbu(t) is plotted with t' beginning at 0 (starting at tfu) and ending at tstop ( ⁇ tbu total).
- tstop ⁇ tbu total
- a vertical line is plotted at tstop from Pstop to Phydr2.
- a horizontal line is plotted for the duration of ⁇ thydr2.
- Eq. A-4 can be expressed as:
- the drawdown function (Eq. A-l) can also be expressed in terms of the two parameters that characterize the transient pressure data.
- T p flow coefficient ⁇ .37 default) r p probe radius (cm) ⁇ t production time (t dd -t fl ⁇ up , sec)
- the regression parameters are: P f formation pressure (psi) ⁇ time constant (sec) ⁇ pressure constant (psi)
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA002485026A CA2485026C (en) | 2002-05-17 | 2003-05-19 | Formation testing while drilling data compression |
AU2003231520A AU2003231520C1 (en) | 2002-05-17 | 2003-05-19 | Formation testing while drilling data compression |
BR0310098-7A BR0310098A (en) | 2002-05-17 | 2003-05-19 | Method for compressing data collected in a wellbore of a formation, control set for use in a formation tester during drilling, and formation tester during drilling |
GB0427226A GB2405509B8 (en) | 2002-05-17 | 2003-05-19 | Formation testing while drilling data compression |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US38134702P | 2002-05-17 | 2002-05-17 | |
US60/381,347 | 2002-05-17 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2003098266A1 true WO2003098266A1 (en) | 2003-11-27 |
WO2003098266A9 WO2003098266A9 (en) | 2004-04-15 |
Family
ID=29550108
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2003/015921 WO2003098266A1 (en) | 2002-05-17 | 2003-05-19 | Formation testing while drilling data compression |
Country Status (5)
Country | Link |
---|---|
AU (1) | AU2003231520C1 (en) |
BR (1) | BR0310098A (en) |
CA (1) | CA2485026C (en) |
GB (1) | GB2405509B8 (en) |
WO (1) | WO2003098266A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2016182890A1 (en) * | 2015-05-08 | 2016-11-17 | Schlumberger Technology Corporation | Real-time annulus pressure while drilling for formation integrity test |
US10125558B2 (en) | 2014-05-13 | 2018-11-13 | Schlumberger Technology Corporation | Pumps-off annular pressure while drilling system |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7921916B2 (en) * | 2007-03-30 | 2011-04-12 | Schlumberger Technology Corporation | Communicating measurement data from a well |
US10302811B2 (en) * | 2008-08-21 | 2019-05-28 | Weatherford Technology Holdings, Llc | Data reduction of images measured in a borehole |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4803873A (en) * | 1985-07-23 | 1989-02-14 | Schlumberger Technology Corporation | Process for measuring flow and determining the parameters of multilayer hydrocarbon producing formations |
US6473696B1 (en) * | 2001-03-13 | 2002-10-29 | Conoco Inc. | Method and process for prediction of subsurface fluid and rock pressures in the earth |
Family Cites Families (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6714872B2 (en) * | 2002-02-27 | 2004-03-30 | Baker Hughes Incorporated | Method and apparatus for quantifying progress of sample clean up with curve fitting |
US6672386B2 (en) * | 2002-06-06 | 2004-01-06 | Baker Hughes Incorporated | Method for in-situ analysis of formation parameters |
-
2003
- 2003-05-19 BR BR0310098-7A patent/BR0310098A/en not_active IP Right Cessation
- 2003-05-19 WO PCT/US2003/015921 patent/WO2003098266A1/en not_active Application Discontinuation
- 2003-05-19 AU AU2003231520A patent/AU2003231520C1/en not_active Ceased
- 2003-05-19 GB GB0427226A patent/GB2405509B8/en not_active Expired - Lifetime
- 2003-05-19 CA CA002485026A patent/CA2485026C/en not_active Expired - Lifetime
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4803873A (en) * | 1985-07-23 | 1989-02-14 | Schlumberger Technology Corporation | Process for measuring flow and determining the parameters of multilayer hydrocarbon producing formations |
US6473696B1 (en) * | 2001-03-13 | 2002-10-29 | Conoco Inc. | Method and process for prediction of subsurface fluid and rock pressures in the earth |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10125558B2 (en) | 2014-05-13 | 2018-11-13 | Schlumberger Technology Corporation | Pumps-off annular pressure while drilling system |
WO2016182890A1 (en) * | 2015-05-08 | 2016-11-17 | Schlumberger Technology Corporation | Real-time annulus pressure while drilling for formation integrity test |
US10419018B2 (en) | 2015-05-08 | 2019-09-17 | Schlumberger Technology Corporation | Real-time annulus pressure while drilling for formation integrity test |
Also Published As
Publication number | Publication date |
---|---|
AU2003231520A1 (en) | 2003-12-02 |
GB2405509B (en) | 2006-09-06 |
CA2485026C (en) | 2009-05-12 |
WO2003098266A9 (en) | 2004-04-15 |
CA2485026A1 (en) | 2003-11-27 |
AU2003231520C1 (en) | 2008-08-28 |
AU2003231520B2 (en) | 2007-11-08 |
BR0310098A (en) | 2005-02-15 |
GB2405509A (en) | 2005-03-02 |
GB2405509B8 (en) | 2007-01-08 |
GB0427226D0 (en) | 2005-01-12 |
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