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Methods for forming a portion of a wellbore are provided. The well is drilled from a first selected depth to a second selected depth to form a bore through a surrounding earth formation. A fluid heating apparatus is disposed within the bore on a working string. Fluid is then heated by moving the fl

Methods for forming a portion of a wellbore are provided. The well is drilled from a first selected depth to a second selected depth to form a bore through a surrounding earth formation. A fluid heating apparatus is disposed within the bore on a working string. Fluid is then heated by moving the fluid through the fluid heating apparatus in the wellbore. The process of circulating fluid adjacent the earth formation serves to also heat the surrounding formation so as to increase the fracture gradient. The fluid heating process may be conducted during a drilling procedure. Alternatively, the fluid heating process may be conducted in connection with a liner hanging and cementing process. A fluid flow restrictor is provided along a run-in assembly that serves to warm the fluids as they are circulated. The warm fluids provide convective heat to the surrounding earth formation, thereby reducing the formation's fracture gradient.

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We claim: 1. A method for forming a portion of a wellbore, comprising the steps of: drilling a well from a first selected depth to a second selected depth to form a bore through a surrounding earth formation; disposing a fluid heating apparatus along the bore; heating fluid by moving the fluid thro

We claim: 1. A method for forming a portion of a wellbore, comprising the steps of: drilling a well from a first selected depth to a second selected depth to form a bore through a surrounding earth formation; disposing a fluid heating apparatus along the bore; heating fluid by moving the fluid through the fluid heating apparatus within the wellbore; and heating the surrounding earth formation by circulating the heated fluid adjacent the earth formation, thereby increasing the fracture resistance of the formation. 2. The method for forming a portion of a wellbore of claim 1, wherein the fluid heating apparatus is a tool that converts hydraulic energy to thermal energy. 3. The method for forming a portion of a wellbore of claim 1, wherein the fluid heating apparatus is a fluid flow restrictor. 4. The method for forming a portion of a wellbore of claim 2, further comprising the steps of: running a liner into the bore; and cementing the liner in place in the bore after the surrounding formation has been heated along a selected length. 5. The method for forming a portion of a wellbore of claim 4, wherein: the liner is run into the bore on a liner hanger assembly; and the fluid flow restrictor is disposed on a run-in assembly for the liner hanger assembly. 6. The method for forming a portion of a weilbore of claim 5, wherein the fluid flow restrictor is a reduced inner diameter portion along an elongated inner pipe of the run-in assembly. 7. The method for forming a portion of a weilbore of claim 6, wherein: the run-in assembly comprises: the elongated inner pipe; a retrievable seal mandrel disposed along the inner pipe; and a stinger connected to the elongated inner pipe below the retrievable seal mandrel; and the step of heating the surrounding earth formation is accomplished by circulating the fluid through the inner pipe and connected stinger, and then through an annular region formed between the stinger and the surrounding liner. 8. The method for forming a portion of a wellbore of claim 7, wherein the run-in assembly further comprises at least one annular flow restrictor disposed between the stinger and the surrounding liner, the at least one annular flow restrictor having one or more bypass paths so as to further restrict the flow of and heat the circulated fluid while permitting fluids to flow up the annular region. 9. The method for forming a portion of a wellbore of claim 1, wherein: the fluid is a drilling fluid; the fluid heating apparatus is a fluid flow restrictor disposed along a working string, the working string having a bore and also having a drill bit at an end; and the step of heating the surrounding earth formation is accomplished by circulating the drilling fluid through the fluid flow restrictor along on the working string, through the drill bit, and then through an annular region disposed between the working string and the surrounding earth formation. 10. A method for drilling a wellbore, comprising the steps of: drilling a well to a first selected depth to form a bore through earth formations; fixing a string of casing in the bore to form a wellbore; determining formation fracture resistance of the earth formation proximate the bottom of the weilbore; calculating an equivalent circulating density (ECD) of drilling fluid to offset formation pore pressure proximate the bottom of the wellbore for further drilling without exceeding the formation fracture resistance; and increasing the fluid density above the calculated ECD in anticipation of increased formation fracture resistance when the drilling fluid is heated. 11. The method of claim 10, wherein the step of determining formation fracture resistance is accomplished by performing a leak-off test. 12. The method of claim 10, further comprising the steps of: running a working string with a drill bit into the wellbore; drilling the well to a second depth to extend the bore, thereby forming an annular region between the working string and the surrounding earth formation; circulating drilling fluid having the increased density through the working string and back up the annular region; and heating the drilling fluid in the working string while the drilling fluid is being circulated. 13. The method of claim 12, further comprising the steps of: adding energy to the drilling fluid circulated in the annular region to reduce hydrostatic pressure on the earth formation; and further increasing the calculated fluid density to compensate for energy added to the drilling fluid in the annular region. 14. The method of claim 12, wherein the step of heating the drilling fluid is accomplished by circulating the fluid through a fluid flow restrictor disposed along the working string. 15. The method of claim 12, further comprising the step of: further increasing the calculated density in anticipation of decreasing the outer diameter of at least a portion of the working string. 16. The method of claim 12, further comprising the step of: further increasing the calculated density in anticipation of decreasing the circulation velocity of the drilling fluid. 17. The method of claim 13, wherein the step of drilling the well to a second depth comprises the steps of: running a working string into the wellbore, the working string having a bore therein, and a drill bit disposed at the end of the working string; and rotating the drill bit; and wherein the step of heating the drilling fluid and the step of adding energy to the drilling fluid are each performed by actuating a downhole turbine and connected annular pump disposed along the working string. 18. The method of claim 17, wherein the downhole annular pump comprises: a stator; a rotor disposed in the stator, the rotor having a bore there though to permit the drilling fluid to flow there through while the drilling fluid is being circulated through the working string; an annular path around the rotor, the annular path permitting the drilling fluid to pass through the pump while the fluid is being circulated through an annular region between the working string and the surrounding wellbore; and blade members on the rotor constructed and arranged to act upon and urge fluid traveling in the annular region. 19. The method of claim 18, wherein the circulation of drilling fluid through the rotor heats the drilling fluid, and also actuates rotational movement of the blade members to add energy to the fluid traveling in the annular region. 20. A method for completing a wellbore, comprising the steps of: forming a wellbore to a selected depth; disposing a fluid heating apparatus along a working string, the working string having a bore therein; running the working string into the wellbore; circulating fluid down into the wellbore through the bore of the working string and through the fluid heating apparatus; circulating fluid back up the wellbore through an annulus formed between the working string and the surrounding wellbore. 21. The method of claim 20, wherein the fluid heating apparatus is a fluid flow restrictor. 22. The method of claim 21, wherein the fluid flow restrictor is a downhole annular pump. 23. The method of claim 22, wherein the pump comprises: a stator; and a rotor disposed in the stator. 24. The method of claim 23, wherein the pump further comprises: a motor operatively connected to the rotor; and the rotor has a bore there though to permit fluid to pass the motor in a first direction. 25. The method of claim 24, wherein the rotor is rotated by fluid pumped through the working string and motor, and wherein the pump further comprises: an annular path around the rotor, the annular path permitting the circulating fluid to pass through the pump in a second direction; and fluid urging means to urge the fluid in the second direction as it passes through the annular path. 26. The method of claim 25, wherein the fluid urging means includes undulations formed on an outer surface of the rotor and conforming undulations formed on an inner surface of a stator portion, the undulations and conforming undulations forming the path through the motor and urging the fluid in the second direction as the rotor rotates relative to the stator portion. 27. The method of claim 26, wherein one side of the undulations of the rotor include blade members helically formed thereon, the blade members constructed and arranged to act upon and urge fluid traveling in the passage. 28. The method of claim 22, wherein the pump is a centrifugal pump that adds energy to the circulated fluid by urging circulated fluid in the annulus upwards. 29. The method of claim 22, wherein the pump is a venturi pump that adds energy to the circulated fluid by urging circulated fluid in the annulus upwards. 30. The method of claim 21, wherein the fluid flow restrictor is a progressive cavity motor. 31. The method of claim 24, wherein the rotor is an electrically actuated motor. 32. The method of claim 20, wherein the circulating fluid is drilling fluid. 33. The method of claim 32 wherein the drilling fluid is a weighted mud. 34. The method of claim 20, wherein the circulating fluid is cement. 35. The method of claim 20, wherein the fluid heating apparatus is a downhole electrical coil. 36. A method for completing a wellbore, comprising the steps of: running a working string into a bore in the earth, the working string having a bore therein, and a drill bit disposed proximate an end of the working string; rotating the working string to drill through an earth formation; circulating a drilling fluid while rotating the drill bit, the fluid being circulated in a first direction through the bore of the working string and the drill bit, and in a second direction through an annular region formed between the working string and the surrounding earth formation; heating the drilling fluid through a flow restriction process while the drilling fluid is being circulated through the working string; and adding energy to the drilling fluid traveling in the annulus to reduce the hydrostatic head in the wellbore. 37. The method of claim 36, wherein the steps of heating the drilling fluid and adding energy to the drilling fluid are each performed by circulating fluid through a downhole turbine and connected annular pump disposed along the working string. 38. The method of claim 37, wherein the downhole annular pump comprises: a stator; a rotor disposed in the stator, the rotor having a bore there though to permit fluid to past the motor in the first direction; a motor operatively connected to the rotor; an annular path around the rotor, the annular path permitting the circulating fluid to pass through the pump in the second direction; and blade members on the rotor constructed and arranged to act upon and urge fluid traveling in the second direction. 39. The method of claim 38, wherein the circulation of drilling fluid through the rotor in the first direction actuates rotational movement of the blade members to add energy to the fluid traveling in the second direction. 40. A run-in assembly for a liner hanger assembly, the liner hanger assembly having a liner hanger for hanging a liner, the run-in assembly comprising: a running tool releasably connectible to the liner hanger assembly; an elongated pipe extending below the running tool configured to be placed within the liner, thereby forming an annular region between the elongated pipe and the surrounding liner; and a fluid heating apparatus disposed along the elongated pipe such that the circulation of fluids through the elongated pipe. 41. The run-in assembly of claim 40, wherein the fluid heating apparatus is a fluid flow restrictor defined by a reduced inner diameter portion of the elongated pipe. 42. The run-in assembly of claim 41, wherein: the run-in assembly further comprises a retrievable seal mandrel; and the elongated pipe comprises: an inner pipe portion along the retrievable seal mandrel; a crossover port joint connected to the inner pipe at a lower end; and a stinger portion connected to the crossover port joint. 43. The run-in assembly of claim 42, further comprising: an annular fluid flow restrictor in the annular area. 44. The run-in assembly of claim 40, further comprising: a circulating bypass apparatus along the inner pipe for selectively bypassing the seal mandrel. 45. The run-in assembly of claim 44, wherein the circulating bypass apparatus defines an upper port and a lower port, and being movable relative to the retrievable seal mandrel to permit the upper and lower ports to selectively straddle the retrievable seal mandrel so that circulated fluids may bypass the retrievable seal mandrel when circulated back to a surface. 46. The run-in assembly of claim 44, wherein the circulating bypass apparatus defines a first valve below the retrievable seal mandrel, and a second valve disposed above the retrievable seal mandrel.