Abstract: An apparatus and methods for forming a transverse fracture in a subterranean formation surrounding a wellbore including measuring a property along the length of the formation surrounding the wellbore, forming a stress profile of the formation, identifying a region of the formation to remove using the stress profile, removing the region with a device in the wellbore, and introducing a fluid into the wellbore, wherein a transverse fracture is more likely to form than if the region was not removed. Some embodiments benefit from computing the energy required to initiate and propagate a fracture from the region, optimizing the fluid introduction to minimize the energy required, and optimizing the geometry of the region.

Abstract: In one possible implementation an in-situ property determination system includes a displacement tool configured for use in a wellbore. The displacement tool includes four or more pads symmetrically located about an axis of the displacement tool, with each pad having a contact surface configured to contact a wall of the wellbore. The four or more pads can extend from a first position proximate an outer surface of the displacement tool to a second position in contact with the wall of the wellbore such that the four or more pads deform the wellbore into an at least approximately circular cross section. The system also includes a recordation device to record force displacement information associated with extending the four or more pads from the first position to the second position.

Abstract: The subject disclosure relates to determining an optimum orientation for perforations around the circumference of a subsurface borehole and optimum wellbore fluid initiation pressure for hydraulic fracturing in anisotropic formations.

Abstract: The subject disclosure relates to determining an optimum orientation for perforations around the circumference of a subsurface borehole and optimum wellbore fluid initiation pressure for hydraulic fracturing in anisotropic formations.

Abstract: A method of performing a cementing operation with an expandable cement deployable into a wellbore penetrating a subterranean formation is provided. The method involves determining design parameters of a wellsite, determining at least one estimated eigenstrain of the expandable cement based on the design parameters, selecting the expandable cement based on the estimated eigenstrain, and validating the selected expandable cement by comparing the estimated eigenstrain with the empirical eigenstrain. The design parameters includes a minimum pre-stress of the wellbore sufficient to prevent creation of a microannulus in the wellbore. The estimated eigenstrain is sufficient to generate the determined minimum pre-stress.

Abstract: An apparatus and methods for forming a transverse fracture in a subterranean formation surrounding a wellbore including measuring a property along the length of the formation surrounding the wellbore, forming a stress profile of the formation, identifying a region of the formation to remove using the stress profile, removing the region with a device in the wellbore, and introducing a fluid into the wellbore, wherein a transverse fracture is more likely to form than if the region was not removed. Some embodiments benefit from computing the energy required to initiate and propagate a fracture from the region, optimizing the fluid introduction to minimize the energy required, and optimizing the geometry of the region.

Abstract: The subject disclosure relates to determining an optimum orientation for perforations around the circumference of a subsurface borehole and optimum wellbore fluid initiation pressure for hydraulic fracturing in anisotropic formations.

Abstract: A self-healing cement for use in wells in which carbon dioxide is injected, stored or extracted, comprises a carbonaceous material. In the event of cement-matrix failure, or bonding failure between the cement/casing interface or the cement/borehole-wall interface, the material swells when contacted by carbon dioxide. The swelling seals voids in the cement matrix, or along the bonding interfaces, thereby restoring zonal isolation.

Abstract: A system and method for performing an adaptive wellsite operation about a wellsite having a sub-surface system with a wellbore formed through at least one subterranean formation, wherein the subterranean formations are configured to store fluid. The system has a containment unit. The containment unit has a static model unit for generating a static model of a subsurface system. The static model unit further has a defect model unit for generating a defect model. The containment unit has a dynamic leak model unit for generating a dynamic leak model. The containment unit has a leak mitigation unit for providing at least one containment plan. The leak mitigation unit and the dynamic leak model unit are integrated for passing data therebetween and whereby the containment plan may be adapted as the static model, the defect model, and/or the dynamic model is generated.

Abstract: Method and apparatus for estimating a fluid driven fracture volume during hydraulic fracturing treatment of a ground formation. A series of tiltmeters are positioned at spaced apart tiltmeter stations at which tilt changes due to the hydraulic fracturing treatment are measurable by those tiltmeters. Tilt measurements obtained from the tiltmeters at progressive times during the fracture treatment are analysed to produce estimates of the fluid driven fracture volume at each of those times as the treatment is in progress. The analysis may be performed sufficiently rapidly to provide real time estimates of the fluid driven fracture volume and may also produce estimates of fracture orientation. The estimates of fracture volume may be compared with the volume of fluid injected to derive an indication of treatment efficiency.

Abstract: Method and apparatus for monitoring growth of fracture during hydraulic fracturing treatment of a ground formation. A series of tiltmeters are positioned at spaced apart tiltmeter stations at which tilt changes due to hydraulic fracturing treatment are measurable by those tiltmeters. Tilt measurements obtained from the tiltmeters at progressive times during the fracture treatment are compared with estimated tilt changes estimated from an assumed hydraulic fracturing propagation. Useful values for initially undetermined values of parameters of the model are derived using an inverse procedure. The data analysis may be performed in real time as the hydraulic treatment progresses using differing propagation models to determine a most probable model.