Geomechanical principles of hydraulic fracturing method in unconventional gas reservoirs

Simple item page
dc.contributor.authorUnwana, Solomon Anwana
dc.contributor.authorOssai, Patrick Godwin Oyindobra
dc.contributor.authorDuru, Ugochukwu Ilozurike
dc.contributor.authorOhia, Princewill Nnaemeka ,
dc.contributor.authorSelegha Abrakasa
dc.date.accessioned2025-12-01T11:27:39Z
dc.date.available2025-12-01T11:27:39Z
dc.date.issued2018-05
dc.descriptionThis research aricle contains figures and tables.
dc.description.abstractUnconventional gas production from shale formation is not new to oil and gas experts worldwide. But our research work was built around hydraulic fracturing technique with focus on the Perkins Kern-Nordgren (PKN) 1972 hydraulic fracturing model(s). It is a very robust and flexible model that can be used on two major shale reservoirs (with the assumption of a fixed height and fracture fluid pressure). The essence was to compare detailed geo-mechanical parameters extracted from wire-line logs with Perkin-C model to select the right well as candidate for simulation. It aided in the prediction production of shale gas from tight shale formations. These also helped in reviewing safe and economical ways of obtaining clean energy sources. Based on similarities in well and formation properties our research team subjected IDJE-2 well (located in the Agbada shale Formation of Niger Delta, Nigeria) to various conditions, equations and assumptions proposed by the study model while also validating our results with the PENOBSCOT L-30 well, located in Canada (with existing profound results from stimulations). The PENOBSCOT L-30 well (Case 1) and IDJE-2 well (Case 2) were both subjected to same conditions, equations and assumptions as applicable to the study model to enable us compare and evaluate stimulation performances. But both cases tend to react differently. However the fluid behavior at constant injection time increases at about 99.64%. Whereas, the maximum width at wellbore shows that a constant increase of fracture width will yield an increase in propant permeability, tensile strength and Poisson’s ratio for Case 1 & 2. Our research results show how rock properties can affect fracture geometry and expected production rates from stimulated shale
dc.identifier.citationUnwana, S. A., Ossai, P. G. O., Duru, U. I., Ohia, P. N. & Selegha A. (2018). Geomechanical principles of hydraulic fracturing method in unconventional gas reservoirs. International Journal of Engineering Work , 5(5). 68-75,
dc.identifier.issn2409-2770
dc.identifier.uriwww.kwpublishers.com
dc.identifier.urihttps://repository.futo.edu.ng/handle/20.500.14562/2321
dc.language.isoen
dc.publisherKambohwell Publisher Enterprises
dc.rightsAttribution-NonCommercial-ShareAlike 4.0 Internationalen
dc.rights.urihttp://creativecommons.org/licenses/by-nc-sa/4.0/
dc.subjectPerkins Kern-Nordgren PKN
dc.subjectHydraulic fracturing
dc.subjectNiger Delta
dc.subjectShale gas
dc.subjectUnconventional gas
dc.subjectgeomechanical principles
dc.subjectDepartment of Petrolem Engineering
dc.titleGeomechanical principles of hydraulic fracturing method in unconventional gas reservoirs
dc.typeArticle

Files

Original bundle
Now showing 1 - 1 of 1
No Thumbnail Available
Name:
Unwana, S. A._Geomechanical_2018.pdf
Size:
526.47 KB
Format:
Adobe Portable Document Format
Download
License bundle
Now showing 1 - 1 of 1
No Thumbnail Available
Name:
license.txt
Size:
1.64 KB
Format:
Item-specific license agreed to upon submission
Description:
Download

Collections

School of Egineering and Engineering Technology