bluuebunny/crossref_metadata_2025_split huggingface dataset:
Litigation Against Unconventional Gas Producers: Lessons from the US Experience
Authors: Lightfoot Richard M 
Published: November 2015

Abstract
"Litigation against unconventional gas producers; lessons from the US experience."
Richard M Lightfoot, Casconsult Pty Ltd
In North America, exploration and production of oil and gas from unconventional sources principally shale, but also tight sandstones and coal seams – is more developed than elsewhere in the world. The presence of large shale, tight gas, and coal seam gas reserves has led to exploration throughout the world.
In Australia, the unconventional gas industry is most developed in Queensland, is seeking to expand in New South Wales and South Australia, and is prospective in Western Australia the Northern Territory, and, to a much lesser extent Victoria.
In the light of the US experience, which has included claims of mechanical failures and inappropriate waste treatment and disposal, leading to groundwater contamination, induced seismicity and hazardous fugitive emissions, government and scientific agencies have produced thousands of studies of the perceived benefits and risks associated with the gas.
In each jurisdiction where unconventional gas extractions has been proposed, governments have been developing legislative regimes for resource allocation and for the managing of risks, through statutes, regulations, standard, and codes of practice.
In the USA, landowners and other citizens who believe that unconventional gas extraction has caused damage to land, water, human and animal health, have resorted to ligation seeking to recover damages, principally by bringing tortuous claims in negligence, nuisance and trespass. In some jurisdiction, actions have also been based on strict liability and legislated rebuttable presumptions of liability.
The paper summarises some cases brought in the USA, to identify the basis of the claims and to analyse their outcomes. In particular, claims brought in tort, and the potential for such claims brought in Australia must be considered.
All sections of the Unconventional Gas Industry need to become aware of their continuing responsibilities. Corporations require an intimate knowledge of the law, its interpretation and the need to minimise exposure to financial, environmental and health risks.
Exporting USA Percussion Tools and Techniques to Australia: Underbalanced Hammer Drilling Significantly Increases ROP On First Attempt Drilling Ultra-Hard/Abrasive Formations
Authors: Rogers Clint , Jangani Reza , Spedale Angelo , Sadawarte Sagar 
Published: November 2015

Abstract
The Mereenie development project is targeting oil and evaluating natural gas reservoirs in the lightly drilled Amadeus Basin. In 2012, an operating company started searching for methods to improve rate of penetration (ROP) drilling the 8¾″ vertical hole section through the difficult Stairway and Pacoota sandstone formations. The lithology consists of very abrasive and hard siltstone/sandstone with UCS up to over 30,000 psi. The hole section starts at 500 m and generally requires 700 m of total wellbore to reach KOP at 1200 m. The section has historically been drilled with PDC and Roller Cone bits with mud as the circulating medium. Both types of BHAs produced unacceptably slow ROP and required multiple trips to reach TD. The operator required a new approach.
To accomplish the objective, the operator wanted to switch from mud to underbalanced drilling using an air percussion BHA equipped with a hammer bit. However, an analysis using a well records database showed that only short (10–30m) shallow surface intervals had been drilled in Australia with percussion air hammers mostly in mining applications in the 1980–90's.
To increase the chance for early success, the operator wanted to import the latest air hammer tools and drilling techniques from North America. The provider suggested taking lessons learned from the Northeast USA where air hammer drilling plays a major role in developing oil and gas reserves in the region. The two applications are similar with regards to formation characteristics and the drilling team concluded the provider's downhole tool technology, service culture and experience/expertise would be integral to project success. In Q4 2013 the provider drilled the fastest and deepest percussion air hammer run in Australia's Oil and Gas history at 24 m/hr, 700% faster than the previous ROP achieved with PDC or Roller Cone.
Proppant Transport Simulation in Hydraulic Fractures and Fracture Productivity Optimization
Authors: Kong Bing , Chen Shengnan , Zhang Kai , Perdomo M. E. 
Published: November 2015

Abstract
The success of hydraulic fracturing stimulation is highly reliant on the flow area and permeability of the induced fractures. The flow area can be significantly affected by proppant distribution while fracture permeability is mainly governed by proppant sizes. To create a fracture with a large flow area, small proppants are essential to maintain a minimum proppant settling velocity; on the other hand, large proppant sizes provide higher proppant pack permeability (i.e., fracture permeability). Therefore, it is critical to study the effect of proppant on the efficiency of hydraulic fracturing stimulation.
In this paper, a 3-D numerical simulator is developed to simulate proppant distribution profile, calculate fracture geometry based on the proppant distribution and forecast productivity through each fracture. More specifically, finite difference method is applied to calculate proppant distribution profile during the hydraulic fracturing and flow back processes for different settings such as proppant size and relative density. Both single-proppant and multi-proppant size combination are investigated and their after-stimulation productivities are compared. Proppant slippage velocity is considered over a wide range of fracturing fluid viscosity and density. Fracture geometry is firstly determined through the hydraulic fracturing operating parameters and then recalculated based on simulated proppant concentration profile. The adjusted fracture geometry is then used to simulate fluid flow from reservoir matrix to the fracture with non-uniform proppant distribution and non-Darcy flow of compressible fluid.
Results show that, among all parameters, reservoir permeability mostly affects proppant size selection and pumping scheduling in order to achieve an optimum fracturing performance. Multi-proppant size combination simulation results indicate that properly designed multi-proppant combination treatment can increase after-stimulation productivity and improve fracture performance. There exists an optimum combination of proppants size and their volume portion exists for a specific reservoir. The approach presented here can help further understand proppant transport and settling, fracture geometry variation and fracture production performance.
Mechanistic Modelling of Counter-Current Slug Flows in Vertical Annuli
Authors: Firouzi Mahshid , Towler Brian F. , Rufford Thomas E. 
Published: November 2015

Abstract
A range of mathematical models and correlations is used to estimate the pressure drop for co-current two-phase flows in vertical wells in the conventional oil and gas industry. However, in the annulus between casing and tubing of a coal seam gas (CSG) well, the upward flow of gas and downward flow of water results in counter-current two-phase flows. The flow regimes developed in such a counter-current system are noticeably different to co-current flow regimes, and thus the existing models used to predict pressure profiles in co-current wells do not adequately describe two phase flows in a (pumped) CSG well.
In this study, we modified existing mechanistic models for co-current flow and counter-current flow in a pipe to predict liquid holdup and pressure profiles of counter-current flows in vertical annuli for the slug flow, which is the dominant flow regime. A model, based on the work of Taitel and Barnea (1983), was also developed to predict the transition from slug flow to annular flow in counter-current flows in annuli. Our comparison of the pressure profiles of co-current and counter-current flows in annuli for the slug flow regime indicates that the pressure loss of counter-current flows could be appreciably different to that in co-current flows under the same conditions. This highlights the need to modify the models that are currently applied in typical commercial well flow simulators to better predict the pressure drop across CSG wells.
A Unique Hydraulic Fracturing Technique Using Dynamic Rock Behavior and Temporary Changes in Geomechanic Stress Anisotropy to Optimize Hydrocarbon Recovery in Unconventional Formations
Authors: Lewis Bryan J. , Surjaatmadja Jim B. 
Published: November 2015

Abstract
In an effort to improve hydrocarbon recovery in unconventional formations, a new stimulation method was developed to take advantage of microtectonic forces created during the hydraulic fracturing process which modify the local stress anisotropy near the wellbore for a short period of time. Because of the temporary changes in the rock stress landscape from creating and extending an initial hydraulic fracture, a brief time window exists following that fracture creation wherein a secondary hydraulic fracture can be created in a similar location in a completely different direction. The second fracture provides direct connectivity to previously unattainable locations in the formation. As a result of the increased formation connectivity, a significant increase in well production is achievable. This new stimulation method greatly enhances the state-of-the-art in hydraulic fracturing, and challenges the industry to develop improved understanding of not only the static behavior of formation rocks, but also their transient behavior.
This paper presents operational recommendations for conducting a multioriented hydraulic fracture (MOHF) treatment using abrasive hydra-jet assisted pinpoint hydraulic fracturing, a financial evaluation of the potential benefits of the MOHF process, and the results from a novel transient three dimensional (3D) geomechanics computational simulation of the creation of dual fractures in a formation. Details of the model are provided in addition to recommendations for improving the accuracy of the model for future application.
SRV Analysis of Shale Gas Wells in China
Authors: Pang Wei , He Zuqing , Xin Cuiping , Du Juan , Sun Zhiyu 
Published: November 2015

Abstract
China owns the world's largest shale gas reserve and is the third country gaining shale gas breakthrough in the world besides the North America. Fuling in Sichuan basin is the first industrially exploited shale gas play in China. Fuling shale gas wells gain good production performance, and the gas rate of some wells are as high as 0.6 million m3 during production test period. However, we still haven't get good understanding of SRV, one vital indicator to evaluate the performance of hydraulic fracturing in Fuling shale gas play.
Production rate and pressure transient analysis by rate normalized pressure (RNP) and rate normalized pressure derivative (RNP’) method is adopted. The SRV of the pilot wells in Fuling shale gas play is estimated from the boundary dominated flow in the RNP and RNP’ log-log interpretation plot. In order to quantify the influence of parameters on SRV, statistical analyses are conducted on fourteen parameters categorized by three kinds including formation, stimulation, and well parameters.
Results show that the parameters are angle between horizontal lateral and minimum stress direction, TOC, absolute open flow (AOF) potential, cumulative gas in first three months, injected fluid volume, porosity, injected fluid volume per stage, fractured clusters, fractured stages, injected proppant volume, flowback recovery in first three months, injected proppant volume per stage, proppant concentration, and horizontal lateral length sorted by the influence on SRV in descending order. The first five parameters have relative strong correlation with SRV. High TOC, porosity and cumulative gas production in early days are good indication of high SRV. Shale gas wells with horizontal lateral paralleled to the minimum stress direction can achieve highest SRV. The other nine parameters, especially proppant concentration and horizontal length show very weak influence on SRV.
The negative correlation of proppant concentration on SRV may have been caused by ineffective fractures (networks), and a positive correlation can be achieved by detailed research of geology and engineering "sweet points" and improved hydraulic fracturing techniques to control fracture propagation. The relationship between SRV and flowback recovery may have been disturbed by offset well's interference during hydraulic fracturing and production.
Managing the Productive and Responsible Use of Energy Resources - The Role of the Regulator
Authors: Stone M.. , Grundy J.. , Troup A.. 
Published: November 2015

Abstract
This paper describes evolving energy resource regulation within Queensland, with emphasis on optimising the State's petroleum resources. Key elements of a proposed resource tenures management framework and reforms to geoscientific information reporting are discussed in the context of petroleum industry trends. A discussion on the role of the regulator provides context to these reforms.
Queensland is a world class resources province within a globally competitive market. The sector produces significant quantities of bauxite, coking coal, lead, silver, zinc and coal seam gas (CSG) and is vital to sustaining economic development and growing jobs within the State.
Queensland's petroleum tenures management framework continues to evolve, to meet industry and stakeholder needs. In September 2015, the Minister for Natural Resources and Mines released the government's Innovative resources tenures framework – Policy position paper. The paper identifies aspects of the current tenures framework which do not work effectively within a modern and globalised resources sector. An innovative and contemporary framework – designed to strike the right balance between resource development, environmental sustainability and investment attraction – is proposed.
Geoscientific data reported by petroleum tenure holders enhances knowledge of the State's resources and valuably informs pre-competitive resource assessment and exploration and development opportunities. Ongoing Department of Natural Resources and Mines (DNRM) reform aims to improve delivery of quality geoscience data to the sector while reducing regulatory reporting burden.
Finally, the paper highlights typical resource activity challenges and how these can be met through effective dialog between the tenure holder and DNRM. As in other areas of venture management, such a dialog can be used to address issues before they become critical.
Application of a New Hydraulic Fracturing Simulator in Changbei II, Ordos Basin, P.R. China
Authors: Falser Simon , Nezich Alexander , Nas Lieuwe , Yang Yatao 
Published: November 2015

Abstract
The Changbei basin centred gas reservoir is located in the Palaeozoic clastic sandstone of the Shaanxi formation, Ordos basin, P.R. China. After more than a decade of successful tight gas production history, the development of the field is being expanded to include new target reservoirs. Because of its low intrinsic permeability, hydraulic fracturing stimulations are required to achieve commercial production rates from the target formation.
Fracture diagnostics suggests high fluid efficiencies in a normally faulted stress regime. Recent monitoring data of hydraulic fracturing stimulations during an appraisal campaign indicate fracture height growth containment which is not readily predicted by the current numerical simulators. Non-radioactively traced proppant and post-injection temperature logs suggest that fracture height may be controlled by a combination of stress barriers and shale laminations. However, the current numerical simulators tend to have difficulty predicting the termination of height growth without calibration to post-job data.
A new hydraulic fracturing code currently under development has been used to simulate the fracture treatments in the target formations. This study briefly describes the input data workflow for the new software and highlights the underlying models the simulations are based upon. The discrepancies between the model results are discussed and possible explanations put forward. The study concludes that the new code is a useful addition to the existing software, and that the thermodynamic module enables genuine comparisons with the temperature logs, which in this case are important for investigating the fracture development. The code also gives promisingly accurate pressure evolutions during the treatment when compared to measurements from a well equipped with a downhole gauge.
Boosting Performance of Component Assets Used in Unconventional Resource Plays With Nanolaminated Alloy Coatings
Authors: Lomasney Christina 
Published: November 2015

Abstract
The use of nano-laminated metallic coatings is an emerging technology that is generating products with material property combinations heretofore not possible. Through a patented electrochemical controlled deposition process, precisely defined configurations of layered metal alloys can be applied to a variety of substrates or as near net shapes. The deposition process can be controlled to produce nano-scale layers with unique interfacial properties resulting in corrosion resistance, elastic modulus, strength, hardness, and fracture toughness combinations uniquely different from conventional material processing. This paper will describe the patented process, characterize the as-deposited material, explore the application of nano-laminated nickel based alloys for downhole service environments and evaluate the potential of this coating to improve corrosion resistance, extended service life and improved safety/integrity of pump, valve and tubular assets.1
Optimal Fracing Near Faults - Quantifying the Interaction Between Natural and Hydraulic Fractures Using Geomechanical Modeling
Authors: Umholtz N.. , Ouenes A.. 
Published: November 2015

Abstract
Utilizing the Material Point Method (MPM) and Continuous Fracture Models (CFM), a workflow is presented that combines Geophysical, Geological, and Geomechanical (3G) considerations to address engineering challenges. Fracture models are derived using geologic and geophysical information, as well as mechanical properties. Hydraulic fractures are then simulated and recreate realistic mechanical results. Products of the workflow such as local stress anisotropy and rotations, strain distributions, and the J Integral provide insight into the sometimes unexpected results of fracing efforts, from the standpoint of geomechanics and the impact of natural fracture networks. Considered primarily in this study is the impact of large scale faults on various stages of an unconventional resource's development.
First, in a Wolfcamp study, it is demonstrated that the mechanical activation of a fault known to bring water can be mitigated either by moving the well 640ft further from the fault and accepting an engineered completion which omits two stages still likely to access the fault, or by moving the well over 920 ft to complete the entire length of the well without accessing the fault. A dataset from the Eagle Ford is then used to demonstrate the ability of the workflow to predict 90 degree stress rotations in fault blocks crossed by a well, and suggests how higher stress anisotropies might reduce the ability of hydraulic fracturing to stimulate complex permeability and instead, only access preexisting fractures. Finally, using recently published fault data and seismic data from the Oklahoma Geological Survey, the link between induced seismic events and a geomechanical proxy are explored.
From well placement in relation to a fault, to stage placement in a well which crosses a fault block with a pronounced stress rotation, to prediction of induced seismic events across three Oklahoma counties—the potential of this workflow to address numerous shale concerns is demonstrated. Large scale faults can greatly alter the stress fields, and consequently the potential of a resource-rich rock to be stimulated. These effects are quantified using geomechanical products of the workflow such as stress anisotropy distributions, strain distributions, and the J Integral. The 3G workflow considered here produces multiple geomechanical results which are crucial to a more realistic understanding of how hydraulic fracturing efforts stimulate the reservoir.
Structural Controls on the River Morphology and Sedimentation Pattern in the South Pine River Basin, North Brisbane
Authors: Bhosle B.. , Bhagat D. K. , Barcelona E.. 
Published: November 2015

Abstract
Sedimentary deposits and structural control on the depositional pattern in South Pine River basin has been investigated in the present study. The basin has attracted less attention in the past mainly due to its relatively smaller size and proximity to a larger basin. The basin is thought to carry signatures of past seismic activities and falls in the region south of crisscrossing fault zone. Previous studies in this area by Hofmann (1980) have described the quaternary sedimentation. Regional studies by Hodgkinson et al. (2007) focused on drainage patterns and their structural controls.
Digital elevation models (DEM) have been derived from contours at an interval of 5m available from published topographical maps and spot heights from USGS (2004) combined with sedimentological studies of exposed deposits were carried out along the South Pine River.
A fault trending N-S direction parallel to the major fault trend in this area was identified. The surface manifestations of the subsurface structure include a sudden change in the river morphology, change in the slope derived from DEM, confluence of the tributaries on approaching the fault zone and sudden changes in the sedimentary deposits. Alluvial fan deposits were identified on the downthrown block of the fault. Photographs of the sites were taken to record their characteristics. Minor seismic activity has also been recorded close to this fault (one of which was recorded in 1960) confirming its presence.
A combination of changes in lightning, vertical exaggeration and changes in the field of view of the DEM has proved to be very useful in identifying the location of the structure. This fault is thought to be a part of major fault system on the northern part of the study area. The concentration of fault traces decreases significantly from north to south as depicted from studies by Hodgkinson et al. (2007). Further studies, including but not limited to trenching and ground penetrating radar studies can give important clues on the nature and type of the structure.