Accordingly, this disclosure describes systems, compositions, and methods that may use pelletized diverting agent particulates for diversion, fluid loss control, and/or other subterranean treatments for controlling fluid flow in subterranean formations. In an embodiment, a method comprising: introducing a treatment fluid into a wellbore penetrating a subterranean formation wherein the treatment fluid comprises: a base fluid; a pelletized diverting agent comprising a degradable polymer, wherein the pelletized diverting agent at least partially plugs a zone in the subterranean formation; and diverting at least a portion of the treatment fluid and/or a subsequently introduced fluid away from the zone. In an embodiment, a treatment fluid comprising: a base fluid; and a pelletized diverting agent comprising a degradable polymer.

Accordingly, this disclosure describes systems, compositions, and methods that may use pelletized diverting agent particulates for diversion, fluid loss control, and/or other subterranean treatments for controlling fluid flow in subterranean formations. In an embodiment, a method comprising: introducing a treatment fluid into a wellbore penetrating a subterranean formation wherein the treatment fluid comprises: a base fluid; a pelletized diverting agent comprising a degradable polymer, wherein the pelletized diverting agent at least partially plugs a zone in the subterranean formation; and diverting at least a portion of the treatment fluid and/or a subsequently introduced fluid away from the zone. In an embodiment, a treatment fluid comprising: a base fluid; and a pelletized diverting agent comprising a degradable polymer.

Use of methyl glycine diacetic acid (MGDA) as additive in processes for recovering crude oil and/or gas from subterranean formations, wherein the MGDA is a mixture of L- and D-enantiomers of MGDA or salts thereof, said mixture containing an excess of the respective L-isomer, and the enantiomeric excess (ee) of the L-isomer is in the range of from 10% to 75% Preferably, the process is a processes of acidizing subterranean formations.

A method includes identifying one or more stress regime types along at least a portion of a borehole, where the stress regime types are selected from a normal stress regime, a thrust stress regime and a strike-slip stress regime, and selecting reservoir access locations along the borehole based on the type of stress regime identified along the borehole.

An oilwell treatment composition comprising (i) a solubilizing agent wherein the solubilizing agent comprises a saturated compound of the formula:

H—(OC.sub.aH.sub.2a).sub.x(OC.sub.bH.sub.2b).sub.y—OC.sub.cH.sub.2c+1

where a and b are each independently 1, 3, or 4; c is 1, 2 or 3; x and y each independently, are numbers ranging from 1 to 5; (ii) a solid acid precursor and (iii) an aqueous fluid wherein the mass ratio of the solubilizing agent to the aqueous solution is within the range of about 1:3 to about 1:5 and the mass ratio of the solubilizing agent to the solid acid precursor is within the range of about 3:1 to about 2:1.

A method of increasing recovery of liquid hydrocarbons from subsurface reservoirs, and particularly from those located in tight formations, is disclosed. One aspect includes calculating the in situ fractured formation wettability from real-time measurement of flowback volume and composition. Another aspect includes determining the composition of the fracturing fluid, the overflush or both, that will achieve higher liquid hydrocarbon recovery by increasing the water wettability of rock surfaces within the reservoir. Monitoring of rock-surface wettability through flowback volume and composition profiles allows the above mentioned injectates to be adjusted in the field to achieve maximal recovery. Other methods, apparatuses, and systems are disclosed.

A method for developing a procedure for pretreating a section of a wellbore prior to hydraulic fracturing stimulation of the section of the wellbore includes determining an optimized notch geometry and determining an optimized chemical treatment for the section of the wellbore. The optimized notch geometry is determined by modeling a notch in the section of the wellbore using a computing system, simulating a pressure increase in the section of the wellbore and on the notch from a hydraulic fracturing stimulation, identifying breakdown pressure in the section of the wellbore, and repeating the modeling, simulating, and identifying to determine the optimized notch geometry in the wellbore as the notch having a lowest breakdown pressure. The optimized chemical treatment is determined by determining a rock type in the section of the wellbore and determining a conditioning fluid that reduces the tensile strength of the rock type.

A method for developing a procedure for pretreating a section of a wellbore prior to hydraulic fracturing stimulation of the section of the wellbore includes determining an optimized notch geometry and determining an optimized chemical treatment for the section of the wellbore. The optimized notch geometry is determined by modeling a notch in the section of the wellbore using a computing system, simulating a pressure increase in the section of the wellbore and on the notch from a hydraulic fracturing stimulation, identifying breakdown pressure in the section of the wellbore, and repeating the modeling, simulating, and identifying to determine the optimized notch geometry in the wellbore as the notch having a lowest breakdown pressure. The optimized chemical treatment is determined by determining a rock type in the section of the wellbore and determining a conditioning fluid that reduces the tensile strength of the rock type.

Provided are embodiments for hydrocarbon reservoir development that include the following: identifying proposed well locations within a reservoir boundary, for each location, developing a well plan by: (a) identifying layers of the reservoir located below the proposed location; (b) iteratively assessing the layers (from deepest to shallowest) to identify a deepest “suitable” layer that is not dry, congested, or unsuitable for gas production; and (c) performing the following for the identified layer and the location: (i) determining a borehole configuration for the location; (ii) determining a completion type for the location; and (iii) determining a stimulation treatment for the location, where a well plan for the location (e.g., for use in developing the reservoir) is generated that specifies some or all of a well location, the target layer, a borehole configuration, a completion type, and a stimulation treatment that corresponds to those determined for the proposed well location.

Provided are embodiments for hydrocarbon reservoir development that include the following: identifying proposed well locations within a reservoir boundary, for each location, developing a well plan by: (a) identifying layers of the reservoir located below the proposed location; (b) iteratively assessing the layers (from deepest to shallowest) to identify a deepest “suitable” layer that is not dry, congested, or unsuitable for gas production; and (c) performing the following for the identified layer and the location: (i) determining a borehole configuration for the location; (ii) determining a completion type for the location; and (iii) determining a stimulation treatment for the location, where a well plan for the location (e.g., for use in developing the reservoir) is generated that specifies some or all of a well location, the target layer, a borehole configuration, a completion type, and a stimulation treatment that corresponds to those determined for the proposed well location.