Both of sonic and electrical image logs are very useful data for determination of in-situ stress direction. Borehole breakouts and induced fractures which have been detected by image logs can be used for identification of minimum and maximum stress direction respectively.

You need a repeat survey data known as 4-D seismic data, the baseline data known as 3-D seismic data and well logs. These data must be acquired from the same field.

You may refer to the article I published on stress path determination using seismic inversion

3-D seismic data is just Ok. The bone of contention is usually the know-how of the interpreter. Information such as, pressure and geothermal gradients, strike and dip directions, the orientation of the faults, collapsed crest and rollovers and possibly with the use of some mathematical models ( such as elastic moduli) can effectively be used to predict the stress path of hydrocarbon reservoirs and much more.

I think the stress path he is referring to is the one initiated by production related changes. For one to effectively determine this, you need to integrate dynamic (Time-lapse seismic data) and static data (3-D seismic data. @Richardson Abraham 3-D seismic data may be ok in determining primary stress not secondary stress that may arise from production related effects.

The question is too loosely formulated to give an extensive answer. What you missed:

a) [Critical] Surface deformation data (INSAR, GPS, etc.)

b) [Critical] Petrophysical measures made on core on concerned field or analogs, especially (but not limited to) relative to geomechanics. Associated core pictures.

c) [Critical] Production data in reservoir/field and eventually neighboring fields

d) [Probably important] Reference 3D flow geomechanical, geological simulation and dynamic flow simulation models if they exist.

d) [Likely non critical] Other geophysical records (gravimetry, electromag, etc)

What certainly merit detailing further as a function of who /where you expect to get data and what you want to do:

d) Seismic data: as mentionned above both 2D, 3D and 4D. As a function of what you want to do, you might want to access data at various steps in processing. This might go down to pre-stack.

e) Well logs. You will likely need raw data for VSP and sonic, repeated caliper, radio active bullets (if any) and reference interpretations for initial and repeated formation evaluation logs (including fracture detection analysis).

Note that asking for "everything" is often not a good idea because identifying what exist is often not that straightforward. In most case asking everything will not get you everything. One 3D seismic survey can be given to you as one cube ... or many. It is usually better to dialog around data with sources to get an idea of what exist / what is easily accessed and make sure that you balance the effort between coverage (having all main parameters covered) and quality (having details where you really need them). Such process is typically very dependent of the quality of the relation with the data sources.

@Nyakno jimmy George

If you want to model the stress path (pressure to stress coupling) changes of our hydrocarbon reservoirs during depletion in a realistic way, you better do the stress path test on the target reservoir cores with reservoir fluids (Uniaxial or hydrostatic). Model is a model, all the log based estimations hold some uncertainity till it is calibrated to valid stress path values.