System, program products, and methods for controlling drilling fluid parameters

• US 7,908,034 B2
• Filed: 06/30/2006
• Issued: 03/15/2011
• Est. Priority Date: 07/01/2005
• Status: Expired due to Fees

• Current Assignee: Board of Regents of the University of Texas System (University of Texas System)
• Original Assignee: Board of Regents of the University of Texas System (University of Texas System)
• Inventors: Gray, Kenneth E.
• Primary Examiner(s): Masinick; Michael D
• Application Number:
  US11/994,320
• Publication Number:
  US 20090194330A1
• Time in Patent Office: 1,719 Days
• Field of Search: 700/282, 175/24, 175/25, 175/38, 175/40, 175/48
• US Class Current: 700/282
• CPC Class Codes: E21B 21/062 by mixing components
• CPC Class Codes: E21B 21/08 Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure valve arrangements therefor E21B21/10
• CPC Class Codes: E21B 47/117 Detecting leaks, e.g. from tubing, by pressure testing

Abstract

Embodiments of systems, program products, and methods for controlling drilling fluid parameters are provided. These embodiments, for example, provide dynamic density control with highly adaptive, real-time, process-control and are scalable to any rig, large or small, on land or water. Combined static and dynamic stresses and displacements can be determined continuously at strategic locations in and around the wellbore of a well so that insitu and operational induced pressure window limitations at specific weak-points or other locations of interest are controlled.

Claims

1. A system for controlling drilling fluid attributes and parameters, the system comprising:

a drilling apparatus having at least one casing string cemented within a subterranean wellbore, a combination of the wellbore and the at least one casing string having a plurality of locations of interest located at separate locations;

a drilling string run within the at least one casing string;

an annulus formed between an external surface of the drilling string and inner surface of the innermost at least one casing string;

a drilling fluid inlet;

a drilling fluid outlet;

a drilling fluid circulating through the drilling fluid inlet, down through the drilling string, up through the annulus, and out the drilling fluid outlet;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid entering the drilling string;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid exiting the annulus;

an output port choke in communication with the annulus and the drilling fluid outlet;

a dynamic density control computer in communication with the choke and including a processor and memory associated with the processor to store operating instructions therein;

means for measuring expansion and compressibility of drilling fluid conducting drilling assembly components associated with drilling fluid circulation and compressibility of a surrounding earth formation to formulate a description of the physical behavior of the wellbore components;

means for performing a cased hole pressure test to determine a volume associated with expansion of pressurized drilling fluid carrying components of the drilling assembly during drilling operations;

means for performing an integrity and fracture pressure test to determine integrity of the cement sealing the at least one casing string to the wellbore and fracture pressure of an associated earth formation to thereby determine a dynamic maximum pressure that can exist at a lower end of the casing string without fracturing the associated earth formation or bonding of the cement; and

dynamic density control program product stored in the memory of the dynamic density control computer and including instructions that when executed by the processor of the dynamic density control computer, cause the computer to perform the operations of;

determining separately for each of the plurality of separated locations of interest at least one drilling fluid control variable system limitation of a drilling fluid control variable,

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling,

predicting separately for each of the plurality of separated locations of interest a value of the drilling fluid control variable responsive to each measured drilling fluid parameter value, and

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation.

2. A system as defined in claim 1, wherein the drilling assembly includes a riser, and wherein the cased hole pressure test includes determining a volume associated with expansion of the riser during drilling operations.

3. A system as defined in claim 1, further comprising:

means for detecting an influx into and a loss of drilling fluid from the drilling assembly during drilling operations; and

means for differentiating between drilling assembly component breathing and a fluid kick responsive to detecting an influx of drilling fluid and between drilling assembly component ballooning and lost circulation responsive to detecting a loss of drilling fluid.

4. A system as defined in claim 1, further comprising:

a drilling fluid pump and pump controller with the dynamic density control computer positioned to adjust the pressure of the drilling fluid entering the drilling string to control dynamic pressure at at least one of the plurality of locations of interest responsive to determining approaching a limiting constraint; and

wherein the operation of controlling dynamic pressure further includes the operation of adjusting at least one of the following;

drilling fluid pump pressure, drilling fluid flow rate, drilling fluid temperature, drilling fluid gas composition, and fluid molecular concentration to thereby control dynamic fluid pressure of the drilling fluid.

5. A system as defined in claim 1, further comprising means for controlling one or more of the following:

pressure, volume, density, temperature, fluid composition, and molecular concentration, for both single phase and multiphase drilling fluid when entering the drilling string, when exiting the annulus, and at a plurality of locations along a length inside the drilling string and in the annulus during drilling operations.

6. A system as defined in claim 1,

wherein the at least one casing string is a plurality of casing strings each cemented in the wellbore;

wherein each location of interest includes at least one of the following;

a specific weak point in at least one of the plurality of casing strings, a specific weak point in at least one cement layer surrounding one of the plurality of casing strings, a portion of an earth formation located at the bottom of the wellbore;

wherein the system further comprises a pressure sensitive device positioned adjacent a bottom hole of the wellbore to monitor and transmit pressure data to the dynamic density control computer during drilling operations; and

wherein the operation of controlling a drilling fluid parameter the operation of controlling dynamic pressure simultaneously inside the drilling string, in the annulus, at the choke, and at the bottom of the wellbore.

7. A system as defined in claim 1, further comprising:

an inlet mixing chamber;

an inlet injection pump;

an outlet mixing chamber;

an outlet injection pump;

an inlet heating element associated with the mixing chamber and

wherein the operation of controlling pressure of the drilling fluid includes performing one or more of the following operations;

adjusting the mass of the drilling fluid in the mixing chamber,

adjusting the mass of the drilling fluid in the mixing chamber, and

adjusting inert gas content of the drilling fluid in the mixing chamber.

8. A system as defined in claim 1, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

9. A system for controlling drilling fluid attributes and parameters, the system comprising:

a drilling as apparatus having at least one casing string cemented within a subterranean wellbore, a combination of the wellbore and the at least one casing string having a plurality of locations of interest located at separate locations;

a drilling string run within the at least one casing string;

an annulus formed between an external surface of the drilling string and inner surface of the innermost at least one casing string;

a drilling fluid inlet;

a drilling fluid outlet;

a drilling fluid circulating through the drilling fluid inlet, down through the drilling string, up through the annulus, and out the drilling fluid outlet;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid entering the drilling string;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid exiting the annulus;

an output port choke in communication with the annulus and the drilling fluid outlet;

a pressure gauge positioned adjacent the drilling string to measure drilling fluid pressure during each test;

databases containing the following data in computer readable format accessible to the dynamic density control computer to formulate a description of the physical behavior of the wellbore components;

data indicating parameters of each stratae of earth formation associated with the wellbore,

data indicating pore fluid quantifications within each stratae of earth formation,

data indicating parameters of each casing string,

data indicating parameters of each layer of cement associated with the wellbore, and

data indicating parameters of the drilling fluid within the drilling string and annulus;

a dynamic density control computer in communication with the choke and including a processor and memory associated with the processor to store operating instructions therein; and

dynamic density control program product stored in the memory of the dynamic density control computer and including instructions that when executed by the processor of the dynamic density control computer, cause the computer to perform the operations of;

determining separately for each of the plurality of separated locations of interest at least one drilling fluid control variable system limitation of a drilling fluid control variable,

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling,

predicting a value of the drilling fluid control variable separately for each of the plurality of separated locations of interest responsive to each measured drilling fluid parameter value,

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation,

measuring over time an increase in fluid pressure and volume of fluid pumped into the drilling apparatus, and

generating at least one of the following;

a pressure verses volume curve and a pressure verses volume versus time curve,

determining a maximum dynamic bottom hole pressure at future depths to be drilled responsive to at least a portion of the data in the databases and at least one of a plurality of operational simulations to thereby enhance drilling requirements management, and

determining an effect of mud channels in the casing string cement responsive to at least one of the simulations.

10. A system as defined in claim 9, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

11. A system for controlling drilling fluid attributes and parameters, the system comprising:

a drilling apparatus having at least one casing string cemented within a subterranean wellbore, a combination of the wellbore and the at least one casing string having a plurality of locations of interest located at separate locations;

a drilling string run within the at least one casing string;

an annulus formed between an external surface of the drilling string and inner surface of the innermost at least one casing string;

a drilling fluid inlet;

a drilling fluid outlet;

a drilling fluid circulating through the drilling fluid inlet, down through the drilling string, up through the annulus, and out the drilling fluid outlet;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid entering the drilling string;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid exiting the annulus;

an output port choke in communication with the annulus and the drilling fluid outlet;

a test pump fluid reservoir;

a test pressure pump in fluid communication with an interior conduit of the drilling string and the test pump fluid reservoir to deliver test fluid under pressure to the drilling string to thereby simulate ballooning and breathing that occurs during drilling operations;

a flowmeter positioned in fluid communication between the test pressure pump and the drilling string to monitor a volume of the test fluid delivered to the drilling string;

a pressure gauge positioned in fluid communication with fluid output from the test pump to monitor a pressure of the test fluid delivered to the drilling string;

the fluid reservoir positioned to receive test fluid not lost to encroachment into a rock formation adjacent the lower end of the at least one casing string or cement associated with the at least one casing string, the total test fluid delivered by the test pump equal to test fluid attributable to ballooning plus test fluid lost due to encroachment;

a fluid reservoir level sensor positioned to sense an amount of the test fluid lost to encroachment indicated by a difference in a pre-test fluid level and a post-test fluid level;

a dynamic density control computer in communication with the choke and including a processor and memory associated with the processor to store operating instructions therein;

dynamic density control program product stored in the memory of the dynamic density control computer and including instructions that when executed by the processor of the dynamic density control computer, cause the computer to perform the operations of;

determining the volume of test fluid attributable to ballooning of the drilling apparatus components during drilling operations,

determining at least one drilling fluid control variable system limitation of a drilling fluid control variable separately for each of the plurality of separated locations of interest,

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling,

predicting a value of the drilling fluid control variable responsive to each measured drilling fluid parameter value separately for each of the plurality of separated locations of interest, and

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation.

12. A system as defined in claim 11, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

13. A system for controlling drilling fluid attributes and parameters, the system comprising:

a drilling apparatus having at least one casing string cemented within a subterranean wellbore, a combination of the wellbore and the at least one casing string having a plurality of locations of interest located at separate locations;

a drilling string run within the at least one casing string;

an annulus formed between an external surface of the drilling string and inner surface of the innermost at least one casing string;

a drilling fluid inlet;

a drilling fluid inlet sensor positioned adjacent the drilling fluid inlet;

a drilling fluid bottom wellbore sensor positioned adjacent the bottom of the wellbore;

a drilling fluid outlet;

a drilling fluid outlet sensor positioned adjacent the drilling fluid outlet;

a drilling fluid circulating through the drilling fluid inlet, down through the drilling string, up through the annulus, and out the drilling fluid outlet;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid entering the drilling string;

at least one monitor positioned to monitor drilling fluid parameters of the drilling fluid exiting the annulus;

an output port choke in communication with the annulus and the drilling fluid outlet;

a dynamic density control computer in communication with the choke and including a processor and memory associated with the processor to store operating instructions therein;

dynamic density control program product stored in the memory of the dynamic density control computer and including instructions that when executed by the processor of the dynamic density control computer, cause the computer to perform the operations of;

determining at least one drilling fluid control variable system limitation of a drilling fluid control variable separately for each of the plurality of separated locations of interest,

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling, to include measuring a value of an operationally induced drilling fluid parameter by the inlet sensor at the inlet, by the outlet sensor at the outlet, and by the bottom wellbore sensor,

predicting a value of the drilling fluid control variable responsive to each measured drilling fluid parameter value separately for each of the plurality of separated locations of interest, and

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation; and

one or more of the following simulators accessible to the dynamic density control program product to formulate a description of the physical behavior of the wellbore components;

a wellbore breathing, ballooning, and rebounding simulator positioned to account for expansion and contraction of the wellbore and surrounding volume under dynamic conditions,

a hydraulics loop simulator positioned to determine frictional pressure drop for drilling fluid carrying components throughout the drilling assembly,

a pressure control simulator positioned to provide data to control fluid kicks,

a wellbore stability simulator positioned to determine fracture pressures and collapse pressures of adjacent earth formations,

a hydraulics optimization simulator positioned to provide data to optimize hydraulic energy at a drill bit used to drill the wellbore,

a drilling simulator positioned to determine rate of penetration parameters,

a formation productivity simulator positioned to assess the production impairment due to drilling fluid invasion, and

a geomechanics model positioned to provide data indicating how earth formations react with the drilling apparatus under varying conditions of pressure, temperature, density, and flow rate;

the operation of predicting a value for each control variable separately for each of the plurality of separated locations of interest including the operation of receiving by at least one of the simulators each measured drilling fluid parameter value and returning at least one predicted value.

14. A system as defined in claim 13, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

15. A method of controlling drilling fluid parameters, the method comprising the steps of:

determining at least one drilling fluid control variable system limitation of a drilling fluid control variable separately for each of a plurality of separated locations of interest in a drilling system having at least one casing string cemented in a wellbore and a drilling string positionable therethrough, the step of determining including at least one of the following;

performing at least one cased hole pressure test prior to running the drilling string through the casing string to determine an amount of drilling fluid volume input into the drilling system attributable to ballooning during drilling operations,

performing at least one cased hole pressure test after running the drilling string to determine an amount of drilling fluid volume input into the drilling system attributable to compression of the drilling string during drilling operations, each cased hole pressure test comprising the steps of;

filling the cased wellbore with fluid,

sealing each drilling system fluid supply inlet and outlet,

applying pressure to the fluid by pumping additional fluid into the drilling system by a pressure pump to thereby compress the drilling fluid, radially expand the casing string and associated cement layer, and compress an earth formation surrounding the wellbore,

measuring over time an increase in fluid pressure and volume of fluid pumped into the drilling system,

generating at least one of the following;

a pressure verses volume curve and a pressure verses volume versus time curve,

releasing the pressure to allow return of fluid,

measuring an amount of fluid returning, and

determining a difference between the amount of additional fluid pumped into the drilling system and the amount of fluid returned defining a balloon volume, the difference indicating at least one of the following;

an amount of potential expansion of components of the drilling system due to a high pressure condition, an amount of potential contraction corresponding with removal of the high-pressure condition, and an amount of compressibility of the drilling string due to a high-pressure condition, and

performing a drilling system integrity and fracture pressure test to determine integrity of cement sealing, the casing string to the wellbore to thereby determine a maximum pressure that can exist at the lower end of the casing string without fracturing and associated earth formation or bonding of the cement, to include;

drilling the wellbore below a lower end of the casing string,

circulating drilling fluid through the drilling system,

determining a steady-state dynamic pressure adjacent the bottom hole,

increasing pressure in the drilling system,

detecting a loss in fluid volume greater than the ballooning volume, and

determining fracture pressure responsive to the detecting a loss in fluid volume to thereby determine a maximum dynamic pressure for the respective location of interest;

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling;

determining an effect of mud channels in the casing string cement responsive to results of the cased hole pressure test;

predicting a value of the drilling fluid control variable separately for each of the plurality of separated locations of interest responsive to each measured drilling fluid parameter value; and

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation.

16. A method as defined in claim 15, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the step of controlling includes:

modifying fluid pressure of the drilling fluid delivered to the drilling fluid inlet real-time during drilling operations.

17. A method as defined in claim 15, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the step of controlling includes:

modifying pressure of the drilling fluid at both the drilling fluid inlet and the drilling fluid outlet or directly in the annulus during drilling operations.

18. A method as defined in claim 15, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the step of controlling includes modifying temperature of the drilling fluid delivered to the drilling fluid inlet.

19. A method as defined in claim 15, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the drilling fluid is a multiphase fluid, and wherein the step of controlling includes at least one of the following:

modifying inert gas content of the drilling fluid; and

injecting or bleeding fluid directly from the annulus.

20. A method as defined in claim 15, wherein the drilling fluid is a primarily liquid drilling fluid, and wherein the step of controlling further includes:

modifying the density of the drilling fluid by supplying a gas to the primarily liquid drilling fluid to reduce dynamic pressure at at least one of the plurality of locations of interest.

21. A method as defined in claim 15, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

22. A method of controlling drilling fluid parameters, the method comprising the steps of:

determining at least one drilling fluid control variable system limitation of a drilling fluid control variable separately for each of a plurality of separated locations of interest in a drilling system having at least one casing string cemented in a wellbore and a drilling string positionable therethrough, each location of interest including a separate wellbore component weak point, the step of determining including the step of establishing local wellhead baseline data separately for each of the plurality of separate wellbore component weak points, to include for each wellbore component weak point the steps of;

running a drilling string through the wellbore to account for compressibility of the drilling string when subjected to interior and exterior fluid pressure,

filling at least a portion of the drilling system including the at least one casing string with fluid,

sealing each drilling system fluid supply inlet and outlet,

applying pressure to the fluid by pumping additional fluid into the drilling system by a pressure pump to thereby compress the drilling fluid, radially expand wellbore components of the drilling system, and compress an earth formation surrounding the wellbore,

measuring over time a volume of fluid pumped into the drilling system and a corresponding increase in fluid pressure,

generating at least one of the following;

a pressure verses volume curve and a pressure verses volume versus time curve,

releasing the pressure to allow return of fluid responsive to reaching a preselected pressure limitations,

measuring an amount of fluid returning, and

determining a difference between the amount of additional fluid pumped into the drilling system and the amount of fluid returned, the difference indicating at least one of the following;

an amount of potential expansion of components of the drilling system due to a high pressure condition, an amount of potential contraction corresponding with removal of the high-pressure condition, and an amount of compressibility of a drilling system component due to a high-pressure condition;

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling;

predicting a value of the drilling fluid control variable separately for each of the plurality of separated locations of interest responsive to each measured drilling fluid parameter value;

the step of predicting including the steps of;

establishing a desired bottom hole pressure responsive to a pressure level limitation for each of the plurality of weak points,

monitoring a plurality of drilling fluid mass and energy parameters in real-time for drilling fluid entering and exiting the drilling system, and

executing a plurality of simulations using a corresponding plurality of drilling system simulators responsive to the local well baseline data to determine for each of the plurality of separate wellbore component weak points at least one of the following;

a maximum pressure level and a minimum pressure level to support drilling operations;

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation, to include the step of modifying at least one drilling fluid parameter within at least one of the following;

a drilling string and an annulus of the drilling system, to control the bottom hole pressure within constraints of each pressure level limitation for the plurality of weak points; and

determining a maximum dynamic bottom hole pressure at future depths to be drilled responsive to at least a portion of the local wellhead baseline data results to thereby enhance drilling requirements management.

23. A method as defined in claim 22, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

24. A tangible computer readable medium that is readable by a computer controlling drilling fluid parameters in a drilling system, the computer readable medium storing a set of instructions that, when executed by the computer, cause the computer to perform the following operations, comprising:

determining at least one drilling fluid control variable system limitation of a drilling fluid control variable separately for each of a plurality of separated locations of interest in a drilling system having at least one casing string positioned in a wellbore and a drilling string positionable therethrough, the operation of determining including at least one of the following;

performing at least one cased hole pressure test prior to running the drilling string through the casing string to determine an amount of drilling fluid volume input into the drilling system attributable to ballooning during drilling operations,

performing at least one cased hole pressure test after running the drilling string to determine an amount of drilling, fluid volume input into the drilling system attributable to compression of the drilling string during drilling operations, the operation of performing a cased hole pressure test comprising;

signaling a pump controller of a pressure pump to pump additional fluid into the drilling system to thereby compress the drilling fluid, radially expand the casing string and associated cement layer, and compress an earth formation surrounding the wellbore,

measuring over time an increase in fluid pressure and volume of fluid pumped into the drilling system,

generating at least one of the following;

a pressure verses volume curve and a pressure verses volume versus time curve,

signaling a pump controller of the pressure pump to cease pumping to allow return of fluid,

measuring an amount of fluid returning, and

determining a difference between the amount of additional fluid pumped into the drilling system and the amount of fluid returned, the difference indicating at least one of the following;

an amount of potential expansion of components of the drilling system due to a high pressure condition, an amount of potential contraction corresponding with removal of the high-pressure condition, and an amount of compressibility of the drilling string due to a high-pressure condition, and

performing a drilling system integrity and fracture pressure test to determine integrity of cement sealing the casing string to the wellbore to thereby determine a maximum pressure that can exist at the lower end of the casing string without fracturing and associated earth formation or bonding of the cement;

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling;

predicting separately for each of the plurality of separated locations of interest a value of the drilling fluid control variable responsive to each measured drilling fluid parameter value; and

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation.

25. A computer readable medium as defined in claim 24, wherein the operation of controlling includes modifying fluid pressure of the drilling fluid delivered to a drilling fluid inlet for the drilling system inlet real-time during drilling operations.

26. A computer readable medium as defined in claim 24, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the operation of controlling includes modifying pressure of the drilling fluid at both the drilling fluid inlet and the drilling fluid outlet during drilling operations.

27. A computer readable medium as defined in claim 24, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the operation of controlling includes modifying temperature of the drilling fluid delivered to the drilling fluid inlet.

28. A computer readable medium as defined in claim 24, wherein the controlled drilling fluid parameter is dynamic pressure, and wherein the drilling fluid is a multiphase fluid, and wherein the operation of controlling includes modifying inert gas content of the drilling fluid.

29. A computer readable medium as defined in claim 24, wherein the drilling fluid is a primarily liquid drilling fluid, and wherein the operation of controlling further includes modifying the density of the drilling fluid by supplying a gas to the primarily liquid drilling fluid to reduce dynamic pressure at at least one of the plurality of locations of interest.

30. A computer readable medium as defined in claim 24, the operations further comprising determining an effect of mud channels in the casing string cement responsive to results of the cased hole pressure test.

31. A computer readable medium as defined in claim 24, wherein a difference between the amount of additional fluid pumped into the drilling system and the amount of fluid returned defines a ballooning volume, and wherein the operation of performing a drilling system integrity and fracture pressure test includes:

determining a steady-state dynamic pressure adjacent the bottom hole of the wellbore;

increasing pressure in the drilling system;

detecting a loss in fluid volume greater than the ballooning volume; and

determining fracture pressure responsive to the detecting a loss in fluid volume to thereby determine a maximum dynamic pressure for the respective location of interest.

32. A computer readable medium as defined in claim 24, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.

33. A tangible computer readable medium that is readable by a computer controlling drilling fluid parameters in a drilling system, the computer readable medium storing a set of instructions that, when executed by the computer, cause the computer to perform the following operations, comprising:

determining at least one drilling fluid control variable system limitation of a drilling fluid control variable separately for each of a plurality of separated locations of interest in a drilling system having at least one casing string positioned in a wellbore and a drilling string positionable therethrough, each location of interest including a separate wellbore component weak point, the operation of determining including the operation of establishing local wellhead baseline data separately for each of the plurality of separate wellbore component weak points, the operation of establishing local wellhead baseline data including for each wellbore component weak point;

signaling a pump controller of a pressure pump to pump additional fluid into the drilling system to thereby compress the drilling fluid, radially expand the casing string and associated cement layer, and compress an earth formation surrounding the wellbore,

measuring over time an increase in fluid pressure and volume of fluid pumped into the drilling system,

generating at least one of the following;

a pressure verses volume curve and a pressure verses volume versus time curve,

signaling a pump controller of the pressure pump to cease pumping to allow return of fluid,

measuring an amount of fluid returning,

determining a difference between the amount of additional fluid pumped into the drilling system and the amount of fluid returned, the difference indicating at least one of the following;

an amount of potential expansion of components of the drilling system due to a high pressure condition, an amount of potential contraction corresponding with removal of the high-pressure condition, and an amount of compressibility of the drilling string due to a high-pressure condition, and

determining a volume of fluid associated with a volume reduction due to compressibility of the drilling string when positioned in the wellbore and when subjected to interior and exterior fluid pressure;

measuring a value of an operationally induced drilling fluid parameter at each of a plurality of separate locations when drilling;

predicting separately for each of the plurality of separated locations of interest a value of the drilling fluid control variable responsive to each measured drilling fluid parameter value;

the operation of predicting including the operations of;

establishing a desired bottom hole pressure responsive to a pressure level limitation for each of the plurality of weak points,

monitoring a plurality of drilling fluid mass and energy parameters in real-time for drilling fluid entering and exiting the drilling system, and

executing a plurality of simulations using a corresponding plurality of drilling system simulators responsive to the local well baseline data to determine for each of the plurality of separate wellbore component weak points at least one of the following;

a maximum pressure level and a minimum pressure level to support drilling operations; and

controlling a drilling fluid parameter responsive to each predicted control variable value and each associated at least one drilling fluid control variable system limitation, to include the operation of modifying at least one drilling fluid parameter within at least one of the following;

a drilling string and an annulus of the drilling system, to control the bottom hole pressure within constraints of each pressure level limitation for the plurality of weak points.

34. A computer readable medium as defined in claim 33, the operations further comprising determining a maximum dynamic bottom hole pressure at future depths to be drilled responsive to at least a portion of the local wellhead baseline data results to thereby enhance drilling requirements management.

35. A computer readable medium as defined in claim 33, wherein the plurality of separated locations of interest comprise a plurality of laterally separated locations of interest.