US3660649A - Apparatus and method for computing drilling costs - Google Patents

Apparatus and method for computing drilling costs Download PDF

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US3660649A
US3660649A US75864A US3660649DA US3660649A US 3660649 A US3660649 A US 3660649A US 75864 A US75864 A US 75864A US 3660649D A US3660649D A US 3660649DA US 3660649 A US3660649 A US 3660649A
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depth
interval
drilling
generating
cost
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Ralph E Gilchrist
Morton E Brown
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Tenneco Oil Co
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    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06G—ANALOGUE COMPUTERS
    • G06G7/00—Devices in which the computing operation is performed by varying electric or magnetic quantities
    • G06G7/48—Analogue computers for specific processes, systems or devices, e.g. simulators
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q30/00—Commerce
    • G06Q30/02—Marketing; Price estimation or determination; Fundraising
    • G06Q30/0283—Price estimation or determination
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q30/00—Commerce
    • G06Q30/02—Marketing; Price estimation or determination; Fundraising
    • G06Q30/0283—Price estimation or determination
    • G06Q30/0284—Time or distance, e.g. usage of parking meters or taximeters

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  • the third signal may be read out and may be graphically UMTED STATES PATENTS recorded as a function of the depth drilled during the interval.
  • This invention relates to apparatus and method for determining the cost per unit length of borehole drilled by a drilling apparatus.
  • the cost of drilling a borehole into the earth with a drilling apparatus in a particular location is a function of the cost of the drill bit, the cost of operating the drilling apparatus per unit length of time, and the speed with which the drill bit penetrates the subterranean formations. Since the drill bit is a consumable apparatus which decreases in efficiency with use and must be replaced periodically, the total drilling time for producing a borehole includes actual bit penetrating time and the trip time required to remove the drill string from the borehole, replace the bit and resume drilling.
  • the apparatus of this invention for determining the cost of drilling a borehole per unit length of hole drilled, as for examplc the cost in dollars per foot drilled, includes first means for generating a first signal representative of incremental lengths of an interval of borehole depth drilled and second means for generating a second signal representative of accumulated drilling costs incurred in drilling the interval of depth. Third means responsive to the first and second signals generate a third signal representative of the average drilling cost per incremental length of borehole drilled.
  • the second means preferably includes fourth means for generating a fourth signal representative of total drilling apparatus time and fifth means for generating a fifth signal representative of drilling cost during the apparatus use time.
  • the fourth means preferably includes sixth means for generating a sixth signal representative of the rotating time of the drilling apparatus and seventh means for generating a seventh signal representative of trip time. Also included are eighth means for generating an eighth signal representative of the cost of the drill bit utilized in drilling the interval of borehole depth.
  • the apparatus of this invention also preferably includes means for reading out the average cost per incremental length of borehole drilled and means for graphically recording the average drilling cost per incremental length of the interval of borehole drilled as a function of the depth drilled during the interval.
  • the method of this invention includes generating the abovedescribed first through eighth signals and graphically recording average drilling costs per incremental length of drilling interval as a function of the depth drilled during the interval.
  • FIG. 1 is a typical graph illustrating the change in drillin cost as a function of depth drilled during an interval of depth.
  • FIG. 2 is a block diagram illustrating the apparatus of the invention.
  • FIG. 3 is a block diagram showing in detail storage unit 4 of FIG. 2.
  • FIG. 4 is a block diagram showing in detail the circuit of trip time unit 6, bit cost unit 14 and rig cost unit 10 shown in FIG. 2.
  • FIG. 1 illustrates a typical graph of average drilling cost as a function of depth drilled over an interval of drilling. This curve is based upon the relationship:
  • Rotating time (t,) is the actual drilling time on each bit.
  • Trip time (t,) is the time expended during the changing of a bit; i.e., the, time required to remove all drill pipe in the borehole, replace the drill bit, and again run all drill pipe back into the borehole to place the new bit on bottomhole. The sum of rotating and trip time (t, t,) is therefore the total rig time required for each drill bit.
  • FIG. 1 Visual examination of the cost per foot curve of FIG. 1 illustrates the optimum or minimum drilling cost for a particular drill bit.
  • drilling costs are declining with accumulated depth.
  • the cost at point B appears to reach an optimum value at which no further decrease in cost is apparent.
  • the interval between point B and point C reflects a slight increase in cost, indicating a decreasing drilling efficiency.
  • Point C can therefore represent the depth at which a new bit should be installed in order to operate at near optimum drilling efficiency.
  • the apparatus and method of this invention allow automatic computation of average drilling cost per incremental length (e.g., per foot) of borehole drilled from the relationship:
  • Rotating time (t,) is a real time variable, but is supplied by an internal source. Borehole depth (d), the second real time variable, must be supplied by an external source.
  • the cost per foot computer is therefore an electronic analog device requiring an input depth signal for each foot of borehole drilled and providing an output voltage proportional to the instantaneous value of the curve of FIG. 1.
  • the preferred embodiment of the cost per foot computer apparatus of this invention is shown in block diagram in FIG. 2.
  • Depth pulses 18 represent the only external variable input required.
  • Depth pulses 18 may be supplied by any convenient signal source compatible with this apparatus and with strip chart recorder 33.
  • One suitable source for pulses 18 is manufactured by W. & L. E. Gurley Company of Troy, N. Y., and bears model No. 8602-1.
  • Pulses 18 are stored in depth storage unit 19, as described below, and are supplied to strip chart recorder 33 which is used to record the output from the computer apparatus and to produce a curve similar to FIG. 1.
  • Recorder 33 may be of any compatible type which is pulse driven in the horizontal plotting direction in order to provide horizontal chart movement proportional to borehole depth increases.
  • One convenient type of recorder 33 is manufactured by Westronics, Inc. of Ft. Worth, Tex. and bears model No. YSDl l-E.
  • Trip time (t,) 6 bit cost (C 14 and rig cost (C,.) 10 are entered into the computer apparatus as constants for any one computation.
  • the internal variable, bit rotating time (t,), is
  • the output of circuit 2 is a series of pulses or clock signals representing a specific time interval. For example, one clock pulse might represent onetenth of an hour.
  • the clock signals are directed via conductor 3 to storage circuit 4 for accumulation and conversion to a proportionate analog DC voltage.
  • FIG. 3 A more detailed diagram of circuit 4 is shown in FIG. 3.
  • Time pulses via conductor 3 are accumulated in digital register 27.
  • the binary output of digital register 27 is applied through conductor 28 to digital-toanalog converter 29.
  • the output of D-to-A converter 29 is applied via conductor 30 to buffer amplifier 31.
  • Amplifier 31 supplies a DC voltage directly proportional to the number of time pulses accumulated by digital register 27. Rotating time voltage is then applied via conductor 5 to adder 8.
  • Trip time (n) is set into the computer by a direct reading potentiometer control in circuit 6.
  • a typical circuit of this type is shown in FIG. 4.
  • the output of circuit 6 is an analog voltage which is directly proportional to trip time.
  • Trip time voltage is applied via conductor 7 to a second input of adder 8.
  • the output of adder 8 is equal to:
  • T t, +1, where T total of rotating time plus trip time.
  • the total time (T) is directed via conductor 9 to multiplier 12.
  • the second input to multiplier 12 is supplied on conductor 11 from rig cost circuit 10. This circuit may be the same as trip time circuit 6 shown in FIG. 4, with an appropriate scale on potentiometer R being provided to allow a direct setting of rig cost.
  • the output of multiplier 12 is an analog DC voltage proportional to:
  • Bit cost (C,,) is manually dialed into the computer by means of a direct reading potentiometer control in circuit 14.
  • This circuit is the same as trip time circuit 6 with an appropriate scale for potentiometer control R: so that the analog DC output voltage is directly proportional to the desired bit cost in dollars.
  • the output of circuit 14 is directed via conductor 15 to the second input of adder 16.
  • Adder 16 combines the signals from multiplier 12 and bit cost circuit 14 to provide an output signal proportional to the total rig cost plus bit cost, or:
  • Depth pulses 18 from the depth retransmission device are directed to storage circuit 19 and to strip chart recorder 33.
  • Storage circuit 19 may be identical to storage cir cuit 4 and is shown in more detail in FIG. 3.
  • depth pulses are accumulated in digital register 27.
  • the binary output of register 27 is directed via conductor 28 to digital-to-analog converter 29.
  • the output of D-to-A converter 29 via conductor 30 and buffer amplifier 31 represents an analog voltage whose absolute value is directly proportional to accumulated depth.
  • the analog output of storage unit 19 is directed via conductor 20 to the second input of analog divider 21.
  • the output of divider 21 represents the desired average cost per foot which is:
  • the analog voltage representing cost per foot is directed via conductor 22 to scaling amplifier circuits 23.
  • One output of circuit 23 is routed via conductor to analog meter 26, providing an instantaneous readout or indication of average cost.
  • the second output of circuit 23 is routed via conductor 24 to the vertical or Y-input of strip chart recorder 33.
  • the horizontal or X-input of strip chart recorder 33 is pulse activated or driven by depth pulses 18 such that the chart is advanced for each pulse or unit of depth.
  • Use of the described incremental advance strip chart recorder allows the curve of FIG. 1 to be automatically plotted.
  • a wide range of resolution may be obtained by proper scaling of computer inputs and recorder functions.
  • the time required to trip the drill string out of the borehole, replace the drill bit and return the bit to the borehole bottom is measured and entered by the drilling operator in circuit 6.
  • the cost of the new bit is entered into circuit 14 and the hourly drilling apparatus cost is entered into circuit 10.
  • rotating time circuit 2 is activated to produce clock pulses which are stored in circuit 4 and a depth recorder (not shown) produces depth pulses 18 which are stored in circuit 19.
  • the computer apparatus thereafter continuously calculates average drilling cost in dollars per foot, which figure is applicable to the interval drilled with the new drill bit. This average drilling cost figure is instantaneously indicated to the drilling operator on meter 26 and is recorded as a function of depth drilled during the interval on recorder 33.
  • the curve produced by recorder 33 will approximate that shown in FIG. 1, with average drilling cost decreasing from point A to point B and increasing thereafter.
  • the drilling operator can detennine when the point of maximum drilling efficiency is passed and a new drill bit is required.
  • a depth recorder (not shown) senses incremental increases in depth during the interval of drilling with each bit and produces signals 18 representative thereof. Circuits 2 through 16 produce a second signal on conductor 17 which is representative of the total operating cost during the time necessary to drill the interval of depth. The signal on conductor 17 is then divided by the depth signal 18 that has been stored in circuit 19 to produce an output signal on conductor 22 representative of the average cost of operating the drilling apparatus for each incremental depth of borehole drilled during the drilling interval. This output signal may be monitored with meter 26 and may be recorded on strip chart recorder 33.
  • Apparatus for determining drilling cost while drilling a borehole comprising:
  • first means for sensing successive incremental lengths of an interval of borehole depth drilled and generating first electrical signals representative thereof
  • second electrical means for generating a second signal representative of accumulated drilling cost incurred as said interval of depth is drilled
  • third means responsive to said first and second signals for generating a third electrical signal representative of average operating cost per incremental length of borehole drilled over said interval of depth.
  • said second means includes:
  • fourth electrical means for generating a fourth signal representative of the length of time said drilling apparatus is utilized in boring said interval of depth
  • fifth means for generating a fifth electrical signal representative of the cost of operating said drilling apparatus during said length of time fifth means for generating a fifth electrical signal representative of the cost of operating said drilling apparatus during said length of time.
  • said fourth means includes:
  • sixth electrical means for generating a sixth signal representative of the rotating time of said drilling apparatus
  • seventh electrical means for generating a seventh signal representative of the amount of time in excess of rotating time that said drilling apparatus is utilized in boring said interval of depth.
  • reading out said third signal as an indication of the average cost per incremental length of borehole drilled.
  • step of generating said second signal includes:
  • step of generating said fourth signal includes:
  • the invention as claimed in claim 12 including:
  • the invention as claimed in claim 12 including:

Abstract

Apparatus and method for computing the cost per unit length of borehole drilled by a drilling apparatus, as for example, the cost per foot of borehole drilled. First signals representative of incremental lengths of an interval of borehole depth drilled and a second signal representative of the accumulated cost incurred in drilling the interval of depth are generated and used to generate a third signal representative of average cost of operating the drilling apparatus during the interval of depth. The third signal may be read out and may be graphically recorded as a function of the depth drilled during the interval.

Description

O-O2-72 XR 396609649 Elite States atent 1151 3,660,649 Gilchrist et al, 51 May 2, 1972 [s41 APPARATUS AND METHGD FOR 2,669,87l 2/1954 Lubinski ..23s/1s4 x COMPUTING DRILLING O TS 3,324,717 6/1967 Brooks 6t 61.. ..73/1s2 2,770,771 11/1956 Schuster ....235/193 x Inventors Ralph Gilchrist, Houston; 3,403,327 9/1968 Welz ....23s/193 x Brown, San Antonio, both of TeX. 2,539,758 l/l95l Silverman et al. ..235/l 84 X [73] Assignee: Tenneco Oil Company, Houston, Tex. I
Primary Exammer-.loseph F. Ruggiero [22] F d p 1970 Attorney-Eugene S. Coddou [21] Appl.No.: 75,864
[57] ABSTRACT Apparatus and method for computing the cost per unit length I 3 3 [52] U s C 2 5/193 7 5 5 3 of borehole drllled by a drilling apparatus, as for example, the [51] Int Cl G068 7 M8 B2) 45/00 cost per foot of borehole drilled. First signals representative of 58 Field 615661;iI1111111111111111111111535/193 151.3 184 61- im'emema' lengths imem" deph d'med 73/151 151 175/40, 346/33 250/83 and a second signal representative of the accumulated cost in- 340/1 166/64 6 324/1 curred in drilling the interval of depth are generated and used to generate a third signal representative of average cost of f operating the drilling apparatus during the interval of depth. [56] Re erences The third signal may be read out and may be graphically UMTED STATES PATENTS recorded as a function of the depth drilled during the interval. 3,364,494 1/1968 Dellinger et al ..73/ 1.5 X 14 Claims, 4 Drawing Figures 2 A e 72 I6 2/ 23 VIEW? a r R; ML L AD DER -IV DER AI 4P} 7' t 5 0 GE ADDER 7' c/Rcull h I L 6 77 l 7 TRIP TIME (It) i 26 CIRCUIT DOZLA RS/ FOOT .RIG COST [6 (Cr) 19/7 cosr (o ciT/? C/RCU' T RECORDER 9 ,1 20 DEPTH (a) DEPTH (d) PULSES STORAGE PATENTEDMAY 2 I972 3, 660,649
SHEET 1 BF 2 DRILLING COST DOLLARS /FOOT FEET OF DEPTH OUTPUT TIME VOLTAGE -D/G/TAL REGISTER ER MANUAL RESET R7 R2 E 7 OPERATIONAL AMP.
Morton E. Brown FIG. 4
Ralph E. Gilchrist INVENTORS BACKGROUND OF THE INVENTION 1. Field of the Invention This invention relates to apparatus and method for determining the cost per unit length of borehole drilled by a drilling apparatus.
2. Description of the Prior Art The cost of drilling a borehole into the earth with a drilling apparatus in a particular location is a function of the cost of the drill bit, the cost of operating the drilling apparatus per unit length of time, and the speed with which the drill bit penetrates the subterranean formations. Since the drill bit is a consumable apparatus which decreases in efficiency with use and must be replaced periodically, the total drilling time for producing a borehole includes actual bit penetrating time and the trip time required to remove the drill string from the borehole, replace the bit and resume drilling.
Heretofore, a drilling operator was required to exercise his own subjective judgment based on his past experience in determining when a drill bit was consumed to the extent sufficient to justify the expensive and non-productive cost of 1 replacing the drill bit. If the drill string is tripped out of the borehole either too soon or too late, the over-all average cost per foot of drilling is increased. In order to minimize drilling costs, it is therefore important to be able to accurately determine the point at which drilling efficiency decreases with continued drilling. No prior art apparatus or method is available to accurately indicate instantaneous drilling efiiciency or to determine the point of maximum drilling efi'rciency.
SUMMARY OF THE INVENTION The apparatus of this invention for determining the cost of drilling a borehole per unit length of hole drilled, as for examplc the cost in dollars per foot drilled, includes first means for generating a first signal representative of incremental lengths of an interval of borehole depth drilled and second means for generating a second signal representative of accumulated drilling costs incurred in drilling the interval of depth. Third means responsive to the first and second signals generate a third signal representative of the average drilling cost per incremental length of borehole drilled.
The second means preferably includes fourth means for generating a fourth signal representative of total drilling apparatus time and fifth means for generating a fifth signal representative of drilling cost during the apparatus use time. The fourth means preferably includes sixth means for generating a sixth signal representative of the rotating time of the drilling apparatus and seventh means for generating a seventh signal representative of trip time. Also included are eighth means for generating an eighth signal representative of the cost of the drill bit utilized in drilling the interval of borehole depth.
The apparatus of this invention also preferably includes means for reading out the average cost per incremental length of borehole drilled and means for graphically recording the average drilling cost per incremental length of the interval of borehole drilled as a function of the depth drilled during the interval.
The method of this invention includes generating the abovedescribed first through eighth signals and graphically recording average drilling costs per incremental length of drilling interval as a function of the depth drilled during the interval.
BRIEF DESCRIPTION OF THE DRAWINGS In the drawings: 1
FIG. 1 is a typical graph illustrating the change in drillin cost as a function of depth drilled during an interval of depth.
FIG. 2 is a block diagram illustrating the apparatus of the invention.
FIG. 3 is a block diagram showing in detail storage unit 4 of FIG. 2.
FIG. 4 is a block diagram showing in detail the circuit of trip time unit 6, bit cost unit 14 and rig cost unit 10 shown in FIG. 2.
DESCRIPTION OF THE PREFERRED EMBODIMENT Referring to the drawings, FIG. 1 illustrates a typical graph of average drilling cost as a function of depth drilled over an interval of drilling. This curve is based upon the relationship:
D=C, (t,+t,)+ C ld where: 6
C,=rig cost in dollars per hour C, bit cost in dollars I, rotating time in hours t, trip time in hours t, t, total drilling time in hours d depth of drilling interval in feet D= average drilling cost in dollars per foot Rotating time (t,) is the actual drilling time on each bit. Trip time (t,) is the time expended during the changing of a bit; i.e., the, time required to remove all drill pipe in the borehole, replace the drill bit, and again run all drill pipe back into the borehole to place the new bit on bottomhole. The sum of rotating and trip time (t, t,) is therefore the total rig time required for each drill bit.
Visual examination of the cost per foot curve of FIG. 1 illustrates the optimum or minimum drilling cost for a particular drill bit. During the interval between A and B, drilling costs are declining with accumulated depth. The cost at point B appears to reach an optimum value at which no further decrease in cost is apparent. The interval between point B and point C reflects a slight increase in cost, indicating a decreasing drilling efficiency. Point C can therefore represent the depth at which a new bit should be installed in order to operate at near optimum drilling efficiency.
The apparatus and method of this invention allow automatic computation of average drilling cost per incremental length (e.g., per foot) of borehole drilled from the relationship:
and provide an output which can be read out or indicated on a meter and can be applied to a strip chart recorder to produce a curve similar to that shown in FIG. 1 for each drill bit used. After a new bit has been installed, but before the drilling is resumed, rig cost (C,), trip time (n) and bit cost (C,,) are entered into the apparatus as known quantities. Rotating time (t,) is a real time variable, but is supplied by an internal source. Borehole depth (d), the second real time variable, must be supplied by an external source.
The cost per foot computer is therefore an electronic analog device requiring an input depth signal for each foot of borehole drilled and providing an output voltage proportional to the instantaneous value of the curve of FIG. 1. The preferred embodiment of the cost per foot computer apparatus of this invention is shown in block diagram in FIG. 2. Depth pulses 18 represent the only external variable input required.
Depth pulses 18 may be supplied by any convenient signal source compatible with this apparatus and with strip chart recorder 33. One suitable source for pulses 18 is manufactured by W. & L. E. Gurley Company of Troy, N. Y., and bears model No. 8602-1. Pulses 18 are stored in depth storage unit 19, as described below, and are supplied to strip chart recorder 33 which is used to record the output from the computer apparatus and to produce a curve similar to FIG. 1. Recorder 33 may be of any compatible type which is pulse driven in the horizontal plotting direction in order to provide horizontal chart movement proportional to borehole depth increases. One convenient type of recorder 33 is manufactured by Westronics, Inc. of Ft. Worth, Tex. and bears model No. YSDl l-E.
Trip time (t,) 6, bit cost (C 14 and rig cost (C,.) 10 are entered into the computer apparatus as constants for any one computation. The internal variable, bit rotating time (t,), is
supplied by rotating time circuit 2. The output of circuit 2 is a series of pulses or clock signals representing a specific time interval. For example, one clock pulse might represent onetenth of an hour. The clock signals are directed via conductor 3 to storage circuit 4 for accumulation and conversion to a proportionate analog DC voltage. A more detailed diagram of circuit 4 is shown in FIG. 3. Time pulses via conductor 3 are accumulated in digital register 27. The binary output of digital register 27 is applied through conductor 28 to digital-toanalog converter 29. The output of D-to-A converter 29 is applied via conductor 30 to buffer amplifier 31. Amplifier 31 supplies a DC voltage directly proportional to the number of time pulses accumulated by digital register 27. Rotating time voltage is then applied via conductor 5 to adder 8.
Trip time (n) is set into the computer by a direct reading potentiometer control in circuit 6. A typical circuit of this type is shown in FIG. 4. The output of circuit 6 is an analog voltage which is directly proportional to trip time. Trip time voltage is applied via conductor 7 to a second input of adder 8. The output of adder 8 is equal to:
T= t, +1, where T total of rotating time plus trip time. The total time (T) is directed via conductor 9 to multiplier 12. The second input to multiplier 12 is supplied on conductor 11 from rig cost circuit 10. This circuit may be the same as trip time circuit 6 shown in FIG. 4, with an appropriate scale on potentiometer R being provided to allow a direct setting of rig cost. The output of multiplier 12 is an analog DC voltage proportional to:
r (r i) This output of multiplier 12 is then applied via conductor 13 to adder 16.
Bit cost (C,,) is manually dialed into the computer by means of a direct reading potentiometer control in circuit 14. This circuit is the same as trip time circuit 6 with an appropriate scale for potentiometer control R: so that the analog DC output voltage is directly proportional to the desired bit cost in dollars. The output of circuit 14 is directed via conductor 15 to the second input of adder 16. Adder 16 combines the signals from multiplier 12 and bit cost circuit 14 to provide an output signal proportional to the total rig cost plus bit cost, or:
rflrds v This voltage representing total cost is directed via conductor 17 to one input of analog divider 21.
Depth pulses 18 from the depth retransmission device (not shown) are directed to storage circuit 19 and to strip chart recorder 33. Storage circuit 19 may be identical to storage cir cuit 4 and is shown in more detail in FIG. 3. In storage circuit 19, depth pulses are accumulated in digital register 27. The binary output of register 27 is directed via conductor 28 to digital-to-analog converter 29. The output of D-to-A converter 29 via conductor 30 and buffer amplifier 31 represents an analog voltage whose absolute value is directly proportional to accumulated depth. The analog output of storage unit 19 is directed via conductor 20 to the second input of analog divider 21. The output of divider 21 represents the desired average cost per foot which is:
The analog voltage representing cost per foot is directed via conductor 22 to scaling amplifier circuits 23. One output of circuit 23 is routed via conductor to analog meter 26, providing an instantaneous readout or indication of average cost. The second output of circuit 23 is routed via conductor 24 to the vertical or Y-input of strip chart recorder 33. The horizontal or X-input of strip chart recorder 33 is pulse activated or driven by depth pulses 18 such that the chart is advanced for each pulse or unit of depth. Use of the described incremental advance strip chart recorder allows the curve of FIG. 1 to be automatically plotted. In addition, a wide range of resolution may be obtained by proper scaling of computer inputs and recorder functions.
In operation, the time required to trip the drill string out of the borehole, replace the drill bit and return the bit to the borehole bottom is measured and entered by the drilling operator in circuit 6. At the same time, the cost of the new bit is entered into circuit 14 and the hourly drilling apparatus cost is entered into circuit 10. As drilling begins, rotating time circuit 2 is activated to produce clock pulses which are stored in circuit 4 and a depth recorder (not shown) produces depth pulses 18 which are stored in circuit 19. As described above, the computer apparatus thereafter continuously calculates average drilling cost in dollars per foot, which figure is applicable to the interval drilled with the new drill bit. This average drilling cost figure is instantaneously indicated to the drilling operator on meter 26 and is recorded as a function of depth drilled during the interval on recorder 33. Because the drill bit is consumable and loses drilling efficiency after a period of use, the curve produced by recorder 33 will approximate that shown in FIG. 1, with average drilling cost decreasing from point A to point B and increasing thereafter. By examining the chart or by monitoring meter 26, the drilling operator can detennine when the point of maximum drilling efficiency is passed and a new drill bit is required.
The method of this invention may be practiced using the apparatus described above. A depth recorder (not shown) senses incremental increases in depth during the interval of drilling with each bit and produces signals 18 representative thereof. Circuits 2 through 16 produce a second signal on conductor 17 which is representative of the total operating cost during the time necessary to drill the interval of depth. The signal on conductor 17 is then divided by the depth signal 18 that has been stored in circuit 19 to produce an output signal on conductor 22 representative of the average cost of operating the drilling apparatus for each incremental depth of borehole drilled during the drilling interval. This output signal may be monitored with meter 26 and may be recorded on strip chart recorder 33.
The foregoing is to be construed as illustrative only and further modifications and alternate equivalent embodiments will be obvious to those skilled in the art in view of this description.
What is claimed is:
1. Apparatus for determining drilling cost while drilling a borehole, comprising:
first means for sensing successive incremental lengths of an interval of borehole depth drilled and generating first electrical signals representative thereof;
second electrical means for generating a second signal representative of accumulated drilling cost incurred as said interval of depth is drilled;
and, third means responsive to said first and second signals for generating a third electrical signal representative of average operating cost per incremental length of borehole drilled over said interval of depth.
2. The invention as claimed in claim 1 including:
means responsive to said third signal for reading out the average cost per incremental length of borehole drilled.
3. The invention as claimed in claim 1 wherein said second means includes:
fourth electrical means for generating a fourth signal representative of the length of time said drilling apparatus is utilized in boring said interval of depth;
and, fifth means for generating a fifth electrical signal representative of the cost of operating said drilling apparatus during said length of time.
4. The invention as claimed in claim 3 wherein said fourth means includes:
sixth electrical means for generating a sixth signal representative of the rotating time of said drilling apparatus;
and, seventh electrical means for generating a seventh signal representative of the amount of time in excess of rotating time that said drilling apparatus is utilized in boring said interval of depth.
5. The invention as claimed in claim 4 including:
eighth electrical means for generating an eighth signal representative of the cost of the drill bit utilized in drilling said interval of depth.
6. The invention as claimed in claim 5 including:
means responsive to said third signal for reading out the average cost per incremental length of borehole drilled.
7. The invention as claimed in claim 5 including:
means for graphically recording said average drilling cost per incremental length of said interval of depth as a function of the depth drilled during said interval.
8. The method of determining drilling costsincluding the steps of:
sensing successive incremental lengths of an interval of borehole depth drilled and generating a first electrical signal representative thereof;
generating a second electrical signal representative of accumulated drilling cost incurred as said interval of depth is drilled;
and, generating a third electrical signal responsive to said first and second signal representative of average operating cost per incremental length of borehole drilled over said interval of depth.
9. The invention as claimed in claim 8 including:
reading out said third signalas an indication of the average cost per incremental length of borehole drilled.
10. The invention as claimed in claim 8 wherein said step of generating said second signal includes:
generating a fourth electrical signal representative of the length of time said drilling apparatus is utilized in boring said interval of depth;
and, generating a fifth electrical signal representative of the cost of operating said drilling apparatus during said length of time.
11. The invention as claimed in claim 10 wherein said step of generating said fourth signal includes:
generating a sixth electrical signal representative of the length of time said drilling apparatus is rotating a drill bit in said borehole;
and, generating a seventh electrical signal representative of the length of time in excess of said rotating time that said drilling apparatus is utilized in boring said interval of depth.
12. The invention as claimed in claim 11 including:
generating an eighth electrical signal representative of the cost of the drill bit utilized in drilling said borehole during said interval of depth.
13. The invention as claimed in claim 12 including:
indicating in response to said third signal the average cost per incremental length of borehole drilled.
14. The invention as claimed in claim 12 including:
graphically recording said average drilling cost per incremental length of said interval of depth as a function of the depth drilled during said interval.
l 4' II I I U. S. PATENT OFFICE v 1 UNITED STATES PATENT OFFICE CEII'IIFICATE OF CORRECTION Patent No. Dated May 972 It is certified that error appears in the above-identified patent and that said Letters Patent are hereby corrected as shown below:
' Column. 2, line 10;
Column 2, line IO;
Column 3, line 60;
should be Signed and sealed this 29th .cay of August 1972.
(SEAL) Attest:
ROBERT GOTTSCHALK Commissioner of Patents EDWARD M.FLETCHER,JR. Attesting Officer

Claims (13)

1. Apparatus for determining drilling cost while drilling a borehole, comprising: first means for sensing successive incremental lengths of an interval of borehole depth drilled and generating first electrical signals representative thereof; second electrical means for generating a second signal representative of accumulated drilling cost incurred as said interval of depth is drilled; and, third means responsive to said first and second signals for generating a third electrical signal representative of average operating cost per incremental length of borehole drilled over said interval of depth.
2. The invention as claimed in claim 1 including: means responsive to said third signal for reading out the average cost per incremental length of borehole drilled.
3. The invention as claimed in claim 1 wherein said second means includes: fourth electrical means for generating a fourth signal representative of the length of time said drilling apparatus is utilized in boring said interval of depth; and, fifth means for generating a fifth electrical signal representative of the cost of operating said drilling apparatus during said length of time.
4. The invention as claimed in claim 3 wherein said fourth means includes: sixth electrical means for generating a sixth signal representative of the rotating time of said drilling apparatus; and, seventh electrical means for generating a seventh signal representative of the amount of time in excess of rotating time that said drilling apparatus is utilized in boring said interval of depth.
5. The invention as claimed in claim 4 including: eighth electrical means for generating an eighth signal representative of the cost of the drill bit utilized in drilling said interval of depth.
6. The invention as claimed in claim 5 including: means responsive to said third signal for reading out the average cost per incremental length of borehole drilled.
7. The invention as claimed in claim 5 including: means for graphically recording said average drilling cost per incremental length of said interval of depth as a function of the depth drilled during said interval.
8. The method of determining drilling costs including the steps of: sensing successive incremental lengths of an interval of borehole depth drilled and generating a first electrical signal representative thereof; generating a second electrical signal representative of accumulated drilling cost incurred as said interval of depth is drilled; and, generating a third electrical signal responsive to said first and second signal representative of average operating cost per incremental length of borehole drilled over said interval of depth.
9. The invention as claimed in claim 8 including: reading out said third signal as an indication of the average cost per incremental length of borehole drilled.
10. The invention as claimed in claim 8 wherein said step of generating said second signal includes: generating a fourth electrical signal representative of the length of time said drilling apparatus is utilized in boring said interval of depth; and, generating a fifth electrical signal representative of the cost of operating said drilling apparatus during said length of time. 11. The invention as claimed in claim 10 wherein said step of generating said fourth signal includes: generating a sixth electrical signal representative of the length of time said drilling apparatus is rotating a drill bit in said borehole; and, generating a seventh electrical signal representative of the length of time in excess of said rotating time that said drilling apparatus is utilized in boring said interval of depth.
12. The invention as claimed in claim 11 including: generating an eighth electrical signal representative of the cost of the drill bit utilized in drilling said borehole during said interval of depth.
13. The invention as claimed in claim 12 including: indicating in response to said third signal the average cost per incremental length of borehole drilled.
14. The invention as claimed in claim 12 including: graphically recording said average drilling cost per incremental length of said interval of depth as a function of the depth drilled during said interval.
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US3761701A (en) * 1971-07-14 1973-09-25 Amoco Prod Co Drilling cost indicator
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US5383129A (en) * 1993-08-31 1995-01-17 Xerox Corporation Method of estimating cost of printing materials used to print a job on a printing apparatus
US6249776B1 (en) * 1998-09-22 2001-06-19 International Business Machines Corporation Methodology for proper weighting of photolithography in the cost of semiconductor products
US6304853B1 (en) 1998-09-21 2001-10-16 Peter J. Malnekoff Automated gemstone evaluation system
US6324527B1 (en) * 1998-09-22 2001-11-27 International Business Machines Corporation Methodology for distinguishing the cost of products in a multiple part number, multiple technology, fully or partially loaded semiconductor fabricator
US20030015351A1 (en) * 1996-03-25 2003-01-23 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system of a given formation
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US20050192855A1 (en) * 2004-01-13 2005-09-01 Greg Chitty System for evaluating over and underbalanced drilling operations
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US20070203723A1 (en) * 2006-02-28 2007-08-30 Segura Michael J Methods for designing, pricing, and scheduling well services and data processing systems therefor
US20100250468A1 (en) * 2009-03-24 2010-09-30 Spl, Inc. System to form an actual sales or delivery value for all components of a commingled hydrocarbon fluid stream
US20100259415A1 (en) * 2007-11-30 2010-10-14 Michael Strachan Method and System for Predicting Performance of a Drilling System Having Multiple Cutting Structures
US7895051B1 (en) * 2009-03-24 2011-02-22 Spl, Inc. Method to form an actual sales or delivery value for all components of a commingled hydrocarbon fluid stream
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US3752966A (en) * 1971-05-28 1973-08-14 Santa Fe Int Corp Drill bit utilization optimizer
US3761701A (en) * 1971-07-14 1973-09-25 Amoco Prod Co Drilling cost indicator
US4128888A (en) * 1977-03-15 1978-12-05 Bj-Hughes Inc. Velocity control arrangement for a computer-controlled oil drilling rig
US4139891A (en) * 1977-03-15 1979-02-13 Bj-Hughes Inc. Elevator load control arrangement for a computer-controlled oil drilling rig
US4794535A (en) * 1986-08-18 1988-12-27 Automated Decisions, Inc. Method for determining economic drill bit utilization
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US5383129A (en) * 1993-08-31 1995-01-17 Xerox Corporation Method of estimating cost of printing materials used to print a job on a printing apparatus
US20050149306A1 (en) * 1996-03-25 2005-07-07 Halliburton Energy Services, Inc. Iterative drilling simulation process for enhanced economic decision making
US7357196B2 (en) 1996-03-25 2008-04-15 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system for a given formation
US7261167B2 (en) 1996-03-25 2007-08-28 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system for a given formation
US20030015351A1 (en) * 1996-03-25 2003-01-23 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system of a given formation
US6612382B2 (en) * 1996-03-25 2003-09-02 Halliburton Energy Services, Inc. Iterative drilling simulation process for enhanced economic decision making
US20040000430A1 (en) * 1996-03-25 2004-01-01 Halliburton Energy Service, Inc. Iterative drilling simulation process for enhanced economic decision making
US20040059554A1 (en) * 1996-03-25 2004-03-25 Halliburton Energy Services Inc. Method of assaying downhole occurrences and conditions
US20040182606A1 (en) * 1996-03-25 2004-09-23 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system for a given formation
US8949098B2 (en) 1996-03-25 2015-02-03 Halliburton Energy Services, Inc. Iterative drilling simulation process for enhanced economic decision making
US7085696B2 (en) 1996-03-25 2006-08-01 Halliburton Energy Services, Inc. Iterative drilling simulation process for enhanced economic decision making
US7032689B2 (en) 1996-03-25 2006-04-25 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system of a given formation
US20050284661A1 (en) * 1996-03-25 2005-12-29 Goldman William A Method and system for predicting performance of a drilling system for a given formation
US7035778B2 (en) 1996-03-25 2006-04-25 Halliburton Energy Services, Inc. Method of assaying downhole occurrences and conditions
US6304853B1 (en) 1998-09-21 2001-10-16 Peter J. Malnekoff Automated gemstone evaluation system
US6324527B1 (en) * 1998-09-22 2001-11-27 International Business Machines Corporation Methodology for distinguishing the cost of products in a multiple part number, multiple technology, fully or partially loaded semiconductor fabricator
US6249776B1 (en) * 1998-09-22 2001-06-19 International Business Machines Corporation Methodology for proper weighting of photolithography in the cost of semiconductor products
US7813935B2 (en) * 2004-01-13 2010-10-12 Weatherford/Lamb, Inc. System for evaluating over and underbalanced drilling operations
US20050192855A1 (en) * 2004-01-13 2005-09-01 Greg Chitty System for evaluating over and underbalanced drilling operations
US8145462B2 (en) 2004-04-19 2012-03-27 Halliburton Energy Services, Inc. Field synthesis system and method for optimizing drilling operations
US20060047527A1 (en) * 2004-08-30 2006-03-02 Caveny William J Determining, pricing, and/or providing well servicing treatments and data processing systems therefor
US7664654B2 (en) * 2004-08-30 2010-02-16 Halliburton Energy Services, Inc. Methods of treating subterranean formations using well characteristics
US7636671B2 (en) * 2004-08-30 2009-12-22 Halliburton Energy Services, Inc. Determining, pricing, and/or providing well servicing treatments and data processing systems therefor
US20070055536A1 (en) * 2004-08-30 2007-03-08 Caveny William J Methods of treating subterranean formations using well characteristics
US20070203723A1 (en) * 2006-02-28 2007-08-30 Segura Michael J Methods for designing, pricing, and scheduling well services and data processing systems therefor
US20100259415A1 (en) * 2007-11-30 2010-10-14 Michael Strachan Method and System for Predicting Performance of a Drilling System Having Multiple Cutting Structures
US8274399B2 (en) 2007-11-30 2012-09-25 Halliburton Energy Services Inc. Method and system for predicting performance of a drilling system having multiple cutting structures
US20110174541A1 (en) * 2008-10-03 2011-07-21 Halliburton Energy Services, Inc. Method and System for Predicting Performance of a Drilling System
US9249654B2 (en) 2008-10-03 2016-02-02 Halliburton Energy Services, Inc. Method and system for predicting performance of a drilling system
US20100250468A1 (en) * 2009-03-24 2010-09-30 Spl, Inc. System to form an actual sales or delivery value for all components of a commingled hydrocarbon fluid stream
US7895051B1 (en) * 2009-03-24 2011-02-22 Spl, Inc. Method to form an actual sales or delivery value for all components of a commingled hydrocarbon fluid stream
US7895134B2 (en) * 2009-03-24 2011-02-22 Spl, Inc. System to form an actual sales or delivery value for all components of a commingled hydrocarbon fluid stream
US7895052B1 (en) * 2009-03-24 2011-02-22 Spl, Inc. Computer instructions to form an actual sales or delivery value for all components of a commingled hydrocarbon fluid stream

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