Abstract: Methods, systems, and computer program products for developing and presenting wellbore pipe string related operation engineering parameter roadmaps in hydrocarbon reservoir modeling are disclosed. A computer-implemented method may include receiving a plurality of depth intervals, associating different computational model calculations with each depth interval, selecting input parameter values for each set of computational model calculations, generating computational model results for each set of computational model calculations associated with each interval to yield a graphical interval plot for the depth interval; and displaying a plurality of graphical interval plots together on a wellbore roadmap. A control list for the roadmap is correspondingly generated and dynamically linked to the wellbore roadmap so that individual entries in the control list are associated with individual interval plots.

Abstract: Methods, systems, and computer program products for range-based sensitivity analysis in hydrocarbon reservoir modeling are disclosed. A computer-implemented method may include receiving a first numeric range defined as a minimum value and a maximum value for a first input parameter of a computational model, computing a different computational model result for each of a plurality of values in the first numeric range by using each of the values as the first input parameter in different respective computational model calculations, and displaying results of the computational model calculations.

Abstract: System and methods for optimizing parameters for drilling operations are provided. A target value of a user-selected operating variable is estimated for each stage of a drilling operation to be performed along a planned well path, based on a first set of wellsite data. Values of one or more drilling parameters are determined for performing each stage of the operation, based on the estimated target value of the operating variable for that stage. The target value of the operating variable is updated based on a second set of wellsite data obtained during a current stage of the operation. The values of the drilling parameters are optimized for subsequent stages of the drilling operation based on the updated target value. The planned path of the well is adjusted for the subsequent stages, based on the optimized drilling parameter values. The subsequent stages are performed along the adjusted path of the well.

Abstract: System and methods for automating well planning and data analysis for downhole operations are provided. Values of one or more operational variables are estimated for each of a plurality of operating intervals, based on a user-selected optimization parameter. The estimated values of the one or more operational variables are provided as inputs to a downhole tool for performing the downhole operation over a current one of the operating intervals along the planned well path. Responsive to receiving an indication that a condition in the well has changed while the downhole operation is performed during the current operating interval, subsequent operating intervals are updated along with the estimated values of the operational variable(s) for each subsequent operating interval. The planned well path is then adjusted by providing the updated values of the operational variable(s) as inputs to the downhole tool for performing the downhole operation over the subsequent operating intervals.

Abstract: Estimating and predicting wellbore tortuosity. At least some of the illustrative embodiments are methods including: receiving, by a computer system, an indication of rotational drilling time and slide drilling time for a wellpath; calculating a value indicative of tortuosity for the wellpath based on the indication of rotational drilling time and slide drilling time for the wellpath; determining, by the computer system, that the wellpath exceeds a tortuosity threshold, the determining based on the value indicative of tortuosity; and changing a drilling parameter regarding the wellpath responsive to determining that the wellpath exceeds the tortuosity threshold.

Abstract: Calibrating Friction Factors. At least some of the illustrative embodiments are methods including: calibrating friction factor for a drilling operation by: plotting on a display device the expected hook load versus depth for the drilling operation; displaying plot points on the display device, each plot point indicative of a measured hook load versus depth for the drilling operation; selecting a plot point associated with a depth, the selecting responsive to a cursor hovering over the plot point on the display device; displaying a friction factor values which correlates the expected hook load versus depth for the particular depth to the measured hook load versus depth for the plot point, selecting the value responsive to the cursor hovering over the value; and then shifting on the display device at least a portion of the indication of expected hook load versus depth based on the value of friction factor.

Abstract: Drilling system and methods may employ a weight-on-bit optimization for an existing drilling mode and, upon transitioning to a different drilling mode, determine an initial weight-on-bit within a range derived from: a sinusoidal buckling ratio, a helical buckling ratio, and the weight-on-bit value for the prior drilling mode. The sinusoidal buckling ratio is the ratio of a minimum weight-on-bit to induce sinusoidal buckling in a sliding mode to a minimum weight-on-bit to induce sinusoidal buckling in a rotating mode, and the helical buckling ratio is the ratio of a minimum weight-on-bit to induce helical buckling in the sliding mode to a minimum weight-on-bit to induce helical buckling in the rotating mode. The ratios are a function of the length of the drill string and hence vary with the position of the drill bit along the borehole.

Abstract: Systems and methods for computer aided pipe string design based on existing string designs are provided. A string type for a current string design is determined based on input received from a user via a graphical user interface (GUI). The GUI enables the user to create the current string design within a graphical design area of the GUI using string components selected from a component selection area of the GUI. A components list is generated based one component data associated with the previously created string designs and a set of component properties that uniquely identify individual components of the previously created string designs. The generated list of components is filtered based on one or more filtering parameters related to the current string design and the previously created string designs. The filtered list for a selected component category is displayed within the component selection area of the GUI.

Abstract: Drilling system and methods may employ a weight-on-bit optimization for an existing drilling mode and, upon transitioning to a different drilling mode, determine an initial weight-on-bit within a range derived from: a sinusoidal buckling ratio, a helical buckling ratio, and the weight-on-bit value for the prior drilling mode. The sinusoidal buckling ratio is the ratio of a minimum weight-on-bit to induce sinusoidal buckling in a sliding mode to a minimum weight-on-bit to induce sinusoidal buckling in a rotating mode, and the helical buckling ratio is the ratio of a minimum weight-on-bit to induce helical buckling in the sliding mode to a minimum weight-on-bit to induce helical buckling in the rotating mode. The ratios are a function of the length of the drill string and hence vary with the position of the drill bit along the borehole.

Abstract: Methods, systems, and computer program products for developing and presenting wellbore pipe string related operation engineering parameter roadmaps in hydrocarbon reservoir modeling are disclosed. A computer-implemented method may include receiving a plurality of depth intervals, associating different computational model calculations with each depth interval, selecting input parameter values for each set of computational model calculations, generating computational model results for each set of computational model calculations associated with each interval to yield a graphical interval plot for the depth interval; and displaying a plurality of graphical interval plots together on a wellbore roadmap. A control list for the roadmap is correspondingly generated and dynamically linked to the wellbore roadmap so that individual entries in the control list are associated with individual interval plots.

Abstract: Methods, systems, and computer program products for range-based sensitivity analysis in hydrocarbon reservoir modeling are disclosed. A computer-implemented method may include receiving a first numeric range defined as a minimum value and a maximum value for a first input parameter of a computational model, computing a different computational model result for each of a plurality of values in the first numeric range by using each of the values as the first input parameter in different respective computational model calculations, and displaying results of the computational model calculations.

Abstract: Calibrating Friction Factors. At least some of the illustrative embodiments are methods including: calibrating friction factor for a drilling operation by: plotting on a display device the expected hook load versus depth for the drilling operation; displaying plot points on the display device, each plot point indicative of a measured hook load versus depth for the drilling operation; selecting a plot point associated with a depth, the selecting responsive to a cursor hovering over the plot point on the display device; displaying a friction factor values which correlates the expected hook load versus depth for the particular depth to the measured hook load versus depth for the plot point, selecting the value responsive to the cursor hovering over the value; and then shifting on the display device at least a portion of the indication of expected hook load versus depth based on the value of friction factor.

Abstract: Estimating and predicting wellbore tortuosity. At least some of the illustrative embodiments are methods including: receiving, by a computer system, an indication of rotational drilling time and slide drilling time for a wellpath; calculating a value indicative of tortuosity for the wellpath based on the indication of rotational drilling time and slide drilling time for the wellpath; determining, by the computer system, that the wellpath exceeds a tortuosity threshold, the determining based on the value indicative of tortuosity; and changing a drilling parameter regarding the wellpath responsive to determining that the wellpath exceeds the tortuosity threshold.