eprintid: 1786
rev_number: 15
eprint_status: archive
userid: 6
dir: disk0/00/00/17/86
datestamp: 2016-12-20 13:39:58
lastmod: 2017-09-20 12:55:25
status_changed: 2016-12-20 13:39:58
type: article
metadata_visibility: show
creators_name: Nelson, Emma J.
creators_name: Chipperfield, Simon T.
creators_name: Hillis, Richard R.
creators_name: Gilbert, John
creators_name: McGowen, Jim
corp_creators: Australian School of Petroleum, The University of Adelaide, Australia,
corp_creators: Santos Ltd, Australia
corp_creators: Australian School of Petroleum, The University of Adelaide, Australia,
corp_creators: Santos Ltd, Australia
corp_creators: Halliburton Australia,
title: Using geological information to optimize fracture stimulation practices in the Cooper Basin, Australia
subjects: O
subjects: RA1
subjects: SG
divisions: SHEER-6
full_text_status: none
keywords: image logs, rock strength, fracture stimulation, in situ stress
abstract: Fracture stimulation treatments of tight formations in the Cooper
Basin can be associated with hydraulic fracture complexity that results in abnormally
high treating pressures, low proppant placement and poor economic success.
Pre-completion (image log and rock testing data) and post-completion data (fracture
stimulation pressure decline plots) were reviewed in 13 treatment zones from the
Cooper Basin. Rock strength, image log and stimulation data were available for
seven of those zones.
From this analysis, a distinct relationship between rock properties (shear and
tensile rock strength), geological weaknesses (natural fractures and other fabrics)
and fracture stimulation complexity (net pressure, near-wellbore pressure loss and
pressure-dependent leak-off) was observed. It is proposed that high in situ stress
(Shmin�0.8 psi ft�1
; 18.1 MPa km�1
), a large contrast in tensile strength between
intact rock (T>1015 psi (7 MPa)) and pre-existing weaknesses in the reservoir (T0)
promote the propagation of fracturing fluid along multiple fracture pathways,
and thus abnormally high treating pressures, low proppant placement and poor
economic success during fracture stimulation treatments in the Cooper Basin.
The methodology used to predict in situ stress and hydraulic fracture complexity
herein presents a potential generic approach that can be used in similar basins where
hydraulic fracture complexity is a problem or where conventional stimulation
practices are unsuccessful.
date: 2007-01
date_type: published
publication: Petroleum Geoscience
volume: 13
publisher: Geological Society
pagerange: 3-16
id_number: doi:10.1144/1354-079306-700
issn: 1354-0793
official_url: http://doi.org/10.1144/1354-079306-700
access_IS-EPOS: limited
owner: Publisher
citation:   Nelson, Emma J. and Chipperfield, Simon T. and Hillis, Richard R. and Gilbert, John and McGowen, Jim  (2007) Using geological information to optimize fracture stimulation practices in the Cooper Basin, Australia.  Petroleum Geoscience, 13.  pp. 3-16. DOI: https://doi.org/10.1144/1354-079306-700 <https://doi.org/10.1144/1354-079306-700>