bluuebunny/crossref_metadata_2025_split huggingface dataset:
Correcting LWD Propagation Resistivity Logs in Horizontal Sinusoidal Wells for Better Water Saturation Estimate: Case Study in a Deepwater, Channelized Turbidite Reservoir
Authors: Wang Hanming , Garrow Patrick , Silva Pablo 
Published: June 2014

Abstract
Today's advanced drilling and geosteering technologies have enabled high-angle horizontal (HAHZ) wells to become common and routine. However, quantitative petrophysical analysis in such an environment is still lagging behind, mainly because of the complexities of the tool response, the lack of fast modeling capabilities and fit-for-purpose softwares. In deepwater channelized turbidite reservoirs, where lateral heterogeneities can be great, a strategy for reducing horizontal well placement risk is the use of sinusoidal pilots. The high deviation angle between the logging while drilling (LWD) tool axis and the formation bedding introduces uncertainty and inaccuracy in the resistivity measurements. These can make petrophysical analysis in HAHZ wells difficult, especially when there are no offset vertical wells available. It is thus necessary that these well deviation effects be corrected before a petrophysical analysis is conducted. In this paper, we first review the tool response characteristics of LWD resistivity logs in HAHZ wells. Then we present a practical workflow to correct for the well deviation effects on LWD resistivity logs through an efficient, highly interactive software, illustrated by both a synthetic data set and several real world examples. It is shown that using this workflow, which can be defined as an interactive inversion, the raw resistivity logs can be significantly corrected to values closer to the true formation resistivity (Rt). The use of Rt instead of the LWD resistivity logs for calculating water saturation (Sw) yields more accurate Sw numbers, which in turn reflect in more accurate reserves estimation. The main challenge is there are still about 30% of logs in the study area are beyond the repair. The development of new hardware with more information content is deserved to address the issue.
An Unconventional Approach to a Conventional Field, how Slickwater has Changed the Game in the Cardium
Authors: Lamson Brad , Keith Don , Zotskine Youssouf , Yule Keri 
Published: June 2014

Abstract
The Pembina oil field in West Central Alberta is known as one of the largest and most prolific conventional oil fields in Canada. Covering more than 283 000 ha (700 000 acres), one of the main hydrocarbon bearing formations being tapped is the Upper Cretaceous Cardium formation. The Cardium is represented by marine sandstone with massive sandstone beds separated by siltstone and silty-mudstone interbeds. Since the 1950's the Cardium has produced an estimated 1.3 billion barrels of light gravity oil and over 12 tcf of gas. With resource potential pegged at 1.2 billion m3 (8 billion barrels) of original oil-in-place, it has the potential to rival some of the most profitable light oil plays being exploited today.
Historically, many conventional fluid systems have been utilized to hydraulically stimulate the Cardium and over-time field development has favored hydrocarbon based systems. This preferential treatment towards hydrocarbons was due to the fact the Cardium has long been known to exhibit a desiccated reservoir character. With the introduction of horizontal drilling and multi-stage completions in 2009, successful development of thinner, lower permeability and porosity sandstones outside of the previously designated Pembina field boundaries ("the halo") was made possible. The methodology and stimulation technique within the Cardium was then reevaluated. As a result, the traditionally considered fluid system evolved to a slickwater based application as an unconventional completion technique was applied to a conventional resource.
This paper will examine the multiple facets of this unconventional approach with a particular focus on a single operator's ingenuity. Despite the concern in introducing a water based completion strategy, the outcome has proved to be beneficial, in fact superior, to previously utilized approaches. Within the West Pembina Cardium halo play, sustained production from various stimulation fluids including the slickwater system will demonstrate the success of this bold initiative.
Utilizing Production Logging Measurement Model Matching to Improve Inflow Control Device (ICD) Completion Design in Offshore Horizontal Wells
Authors: Zorbalas Konstantinos I. , Al Yateem Karam S. , El-Fattah Mahmoud Abd 
Published: June 2014

Abstract
A study was undertaken to evaluate the production performance/potential of horizontal wells equipped with inflow control devices (ICDs) in an offshore oil field in Saudi Arabia. Several challenges are associated with the optimum ICD completion design in this field due to the reservoir sequence of the thick sandstone with thin layers of shale, siltstone and limestone. The sand members are unconsolidated, which poses potential issues with fine migration for screen plugging. An additional challenge to the completion design is the practice of long open hole (OH) horizontal sections, normally drilled with net pay in the range of 3,000-4,000 ft MD with oil based mud (OBM). The reservoir has very good permeability and the high permeability streaks pose a threat of acute water production early in the life of the wells.
Many representative wells were analyzed by constructing a calibrated ICD model based on their actual completion characteristics with ICD completion and the reservoir parameters of each well. The calibrated model was used to match the wells' production logging measurements profile and analyze future performance based on potential enhancements in the completion design. Results showed that using a nozzle based ICD instead of a helical ICD design for the same influx profile in these wells caused a reduction in the pressure drop across the completion. The use of additional isolation packers in the ICD sections has the potential to improve the influx balance profile by creating more compartmentalization in the long OH horizontal sections. These findings are taken under consideration for optimizing the completion practices in the future development of the field.
Application of Linear and Partial Correlation Techniques to Enhance the Waterflooding Surveillance Process
Authors: Villamizar M.. , Rivas F.. , Carvajal G. A. , Md Adnan F.. , Kheterpal A.. , Knabe S.. , Rodriguez J. A , Al-Jasmi A.. , Al-Saad B.. , Goel H. K 
Published: June 2014

AbstractLinear correlation techniques (LCTs) and partial correlation techniques (PCTs) are well known statistical techniques useful in generating smart workflows for real-time surveillance and monitoring processes, such as waterflooding. In real-time environments, which require short-term analysis (30-day cycling), traditional simulation techniques are less effective and take a considerable amount of CPU time. As an alternative and considering LCTs have been widely applied in the oil industry, to understand relationships between producer and injector wells, LCTs can provide rapid results and even predict expected water breakthrough in producer wells.This paper describes the use of the Pearson correlation coefficient (PCC), a statistical measurement that is very sensitive to linear relationships between water injection and producing wells, including correlations where one parameter is a nonlinear function of the other. While this technique can show high correlation between some variables that are unrelated and only small correlations between highly related variables, the use of PCC, in many cases, returns measurements concerning the joint behavior of two variables that are important to the decision-making process.This paper describes how PCC was used to clean noisy data generated in LCTs. This paper also describes the use of the PCT to detect the influence of other variables on the LCT-based results. The study was conducted on a mature, carbonate black-oil reservoir in the Middle East under waterflood. The LCT/PCT results were compared with streamline simulation, and some similarities were found between the streamline simulation well allocation factors and the LCT/PCT results. Regardless of local reservoir conditions, the results showed that LCTs/PCTs are powerful tools that can be used to quickly assess inter-dependencies among producing wells and associated injectors. Use of these tools can enable engineers to make prompt decisions to help prevent water breakthrough and adjust water injection rates.
Understanding Shale Gas Production Mechanisms Through Reservoir Simulation
Authors: Hao Sun , Adwait Chawathe , Hussein Hoteit , Xundan Shi , Lin Li 
Published: June 2014

AbstractShale gas has changed the energy equation around the world, and its impact has been especially profound in the United States. It is now generally agreed that the fabric of shale systems comprise primarily of organic matter, inorganic material and natural fractures. However, the underlying flow mechanisms through these multi-porosity, multi-permeability systems are poorly understood. For instance, debate still exists about the predominant transport mechanism (diffusion, convection and desorption) as well as the flow interactions between organic matter, inorganic matter and fractures. Furthermore balancing the computational burden of precisely modeling the gas transport through the pores versus running full reservoir scale simulation is also contested. To that end, commercial reservoir simulators are developing new shale gas options but some, for expediency, rely on simplification of existing data structures and/or flow mechanisms.We present here the development of a comprehensive multi-mechanistic (desorption, diffusion and convection) multi-porosity (organic materials, inorganic materials and fractures), multi-permeability model that uses experimentally determined shale organic and inorganic material properties to predict shale gas reservoir performance. Our multi-mechanistic model takes into account gas transport due to both pressure-driven convection and concentration-driven diffusion. The model accounts for all the important processes occurring in shale systems, including desorption of multi-component gas from the organics surface, multi-mechanistic organic-inorganic material mass transfer, multi-mechanistic inorganic material-fracture network mass transfer, and production from a hydraulically fractured wellbore.Our results show that Dual-porosity Dual-permeability (DPDP) with Knudsen diffusion is generally adequate to model shale gas reservoir production. By comparing Triple-porosity Dual-permeability (TPDP), DPDP and Single-porosity Single-permeability (SPSP) formulations under similar conditions, we show that Knudsen diffusion is a key mechanism and should not be ignored. We also guide the fractures design by analyzing flow rate limiting steps. This work provides a basis for long-term shale gas production analysis and also helps define value-adding laboratory measurements.
A Comprehensive Experimental Study on Wellbore Strengthening
Authors: Guo Quanxin , Cook John , Way Paul , Ji Lujun , Friedheim James E. 
Published: June 2014

Abstract
Experimental tests have been performed to investigate the applicability, effectiveness and engineering of various wellbore strengthening techniques which increase the mud weight window by adding lost circulation materials (LCM) to drilling fluids. The experimental techniques include fracture sealing of known fracture apertures simulated by two plates, induced or natural fractures in a sandstone or shale block with a borehole, and a transparent cylindrical LCM particles transport cell, which allows visualization of how the fracture seal is formed and broken.
In the block tests, two independent stresses are applied to the block faces parallel to the wellbore to simulate horizontal stress anisotropy. Drilling fluid, with and without LCM, is pumped into the wellbore to simulate formation breakdown, mud loss, fracture sealing and wellbore strengthening. The wellbore strengthening treatments can be continuous in one step or hesitation squeeze in steps. The various types of tests performed to simulate different operational procedures include: breakdown tests under different stress anisotropy and magnitude to establish the baseline and to validate the results with rock mechanics analysis; fracture sealing and remedial treatment of an induced fracture with LCM after breakdown; preventive treatment with background LCM in the active mud system before breakdown to study the difference between preventive versus remedial treatments; and fracture sealing and strengthening of natural fractures of different apertures; among others.
Several hundred tests have been performed with different stress conditions and strengthening implementation methods. Valuable lessons have been learned from this comprehensive experimental study and the results have significantly increased the success of wellbore strengthening. Due to the large volume of test results and data, this paper focuses more on the various types of tests performed using the block tester, and gives selected snapshots of test results and modeling work on wellbore strengthening mechanism and the role of filtercake on sealing quality and strengthening performance. More results will be presented elsewhere.
The IPIECA Marine Geospatial Bibliography
Authors: Voparil Ian , Connick Sarah , Marconi Michele , Engstrom Carol , Ruck Philip 
Published: June 2014

Abstract
Research on marine ecosystems is progressing rapidly, but information is often from disparate sources and in different formats. Although nominally publically available, it is frequently difficult to find, presenting a challenge in ensuring relevant information can be accessed freely and easily by all interested audiences.
IPIECA, the global oil and gas industry association for environmental and social issues, have developed and launched an innovative knowledge sharing platform called the Marine Geospatial Bibliography (MGB). The business case for the development of the MGB is to centralise relevant environmental understanding relating to oil and gas activities in marine areas, ensuring it is transparent and can serve as the basis for policy and regulations, by making it publicly accessible whilst reducing duplication of effort.
The MGB’s mission statement is to ‘‘identify and share sources of up-to-date scientific knowledge for management of oil and gas activities related to the marine environment, biodiversity, and ecosystems, whilst promoting ocean stewardship through increased transparency and greater awareness". The tool centralises and geospatially references reliable information, making it easy to find, search and summarise. The advantages of the MGB include that it: –Supports science-based environmental management enabling licence to operate;–Provides technical/scientific credibility and weight-of-evidence for regulatory decisions;–Allows horizontal transfer of knowledge between different communities of users;–Helps retain critical technical knowledge in the industry beyond the retirement boom
The MGB’s primary audience is the oil and gas industry, however it is also intended to be of use to other audiences. The oil and gas industry often work with consultants who carry out baseline assessments or Environmental Impact Assessments (EIAs) so the information in the MGB could be relevant and useful for them. Additionally, it may be of interest to academics and scientists that perform research on deep water and marine environments. The MGB will also be of use to regulators and policy makers that make decisions based upon best available information to regulate the oil and gas industry. Finally the information contained in the MGB may be of interest to the public.
At launch the MGB contained over 10,000 resources (including key papers, academic references and relevant industry grey literature) with an initial focus on the North Sea and Gulf of Mexico.
This paper will explain the background/rationale for the project, the functionality and applicability of the MGB, and provide additional insight into the resources available. The paper will illustrate how IPIECA members are contributing information to the tool in the interests of greater transparency, and will outline future plans for expansion.
Water Related Risk Assessment
Authors: Pornsakulsakdi L. , Sila A. 
Published: June 2014

Abstract
By 2030, the world may face 40 percent water shortfall as a result of increasing population along with impacts from climate change. This results in rising effort from worldwide companies to fully understand current and future risks including liabilities from water use for their operations.
In response to this growing concern, PTTEP has conducted a project to establish corporate system to assess future potential water related risks on production assets. Boundary of study covers eleven assets located in five countries (Thailand, Oman, Australia, Canada, and Algeria).
Innovative risk assessment is conducted by using both primary information from PTTEP representatives of each asset and secondary data from three worldwide accepted softwares, comprising WBCSD/IPIECA Global Water Tool, WRI Aqueduct Water Risk Atlas, and WWF Water Risk Filter. Since each software presents its unique set of risk indicators, combining all risk results generated by these tools produces higher level of confidence and more accurate results. The system is then capable to undertake scenario analysis to quantify impacts of the pre-defined risk events.
The results indicate that, it is not expecting to have significant risk at PTTEP’s assets in Thailand, Oman, Australia, and Canada. However, a major concern for Algeria assets regarding water stress issue is defined. Algeria is also assessed to pose regulatory risks, particularly in the areas of clarity and enforcement of water-related legal framework. Accordingly, it is vital for PTTEP to be aware and monitor changes in government and public perceptions on water related issues in Algeria.
The outcome of this project is regarded as an innovation to assist PTTEP to pinpoint water-related risks and quantify the magnitude of impacts if the risks occur. The water related risk assessment tool functions like a compass for PTTEP to develop corporate water management plan and define suitable practices for company’s water footprint reduction.
Monitoring of Impact of Drilling Discharges to a Calcareous Algae Habitat in the Peregrino Oil Field in Brazil
Authors: Johnsen Ståle , Nilssen Ingunn , Brandão Pinto Ana Paula , Torkelsen Terje 
Published: June 2014

Abstract
The Peregrino field, operated by Statoil ASA, is located 80km south of Cabo Frio, in the Campos Basin area, Brazil. The field is operated with two well head platforms drilling production and injection wells and a FPSO located between these. The seabed hosts a calcareous algae (CA) habitat, an area with relatively rich biodiversity. Conventional sediment monitoring has been found not to give sufficient information about potential impact of drill cuttings.
A tailor suited, in-situ sensor based monitoring approach was developed for the field including testing and qualification of a number of sensor systems for visual observation, oceanographic parameters, light and turbidity, all placed on a seabed observatory frame. 4, 6-months sampling campaigns were carried out with this system. In addition, three sediment traps were placed at different locations, over totally 7, 4-months campaigns. Data were combined with discharge information and laboratory studies of drill cuttings effects to CA and associated species, to identify potential exposure and impact in the field. Discharge and environmental risk modeling were performed to identify which data gave significant and vital information for the purpose of environmental monitoring of the CA habitat.
Combining discharge information with in-situ observations and modeling gives a strongly improved basis for identifying impact of drill cuttings discharges in a field like Peregrino. Technology for this has been developed to a readiness level available for multiple use. A new, cost beneficial monitoring program is proposed as an alternative to traditional sediment monitoring.
Continuing the Efforts to Learn From Industry Safety Data
Authors: Walker Kirsty , Toutain Patrick , Poore Wendy 
Published: June 2014

Abstract
The International Association of Oil & Gas Producers (OGP) is a global forum in which members identify and share best practices to achieve improvements in areas such as health, safety, the environment, security, social responsibility and operations.
OGP encompasses 74 oil and gas companies, industry associations as well as major upstream service companies. OGP members produce more than half of the world’s oil and about one third of its gas.
The OGP member companies report their annual safety data on a voluntary basis, and the information is used to compile an annual safety performance indicators report. The OGP Safety Data Sub-Committee (SDSC) has focused its attention on using the data submitted by member companies to derive industry-wide learning from the causes of industry incidents. This paper describes the efforts of the OGP SDSC to improve the ability to learn from industry data.
The paper details how the OGP SDSC developed a generic set of causal factors which were reported by participating companies for fatal incidents and high-potential events, based on the annual data submissions from 2010 to 2012. The results from the last three years of data show that the most common causal factors for fatal incidents and high potential events are hazard identification or risk assessment, work standards/procedures, supervision, decision making or judgment, and training/competence and unintentional violations (by individuals or groups).
The paper also discusses how the OGP SDSC developed a set of life saving rules which are used in the analysis of the annual safety data submissions and how analysis of the fatal incident descriptions has shown that 79% of the fatal incidents reported in 2012 are linked to failure to adhere to OGP’s life saving rules.
ESHIA Hindcasts: Advancing Environmental, Social and Health Impact Assessment and Risk Management
Authors: Tait Russell D. , Moynihan Kelly J. , Daetwyler Neil A. , Young Carolyn J. , Scott-Wilson Peter 
Published: June 2014

Abstract
Environmental, Socioeconomic & Health Impact Assessments (ESHIAs) are considerable undertakings that are performed to identify and evaluate the key environmental, socioeconomic and health (ESH) aspects of an activity/project and their associated potential impacts, evaluate appropriate alternatives, propose measures to address ESH risks and fulfill host-country regulatory and/or external financing institution requirements. However, a project’s ESHIA process (as well as the associated process for producing an Environmental, Socioeconomic & Health Management Plan [ESHMP]), its findings and/or the associated documentation that is produced are infrequently revisited during an asset’s operational life. Systematic ESHIA (or ESHIA/ESHMP) hindcasts offer the opportunity to capture lessons learned, identify opportunities to improve the process by which ESHIAs and ESHMPs are synthesized, and develop and implement enhanced environmental, social and health risk management measures. ESHIA/ESHMP hindcasts were conducted for two ExxonMobil assets that are in the middle portion of their operational life – i.e., Angola Block 15 (offshore deep water production) and the Chad Export Project (onshore production). Based on the findings from these investigations, improvements have been integrated into several existing internal ESH management systems and documentation, and the specific process for preparing ESHIAs and ESHMPs for ExxonMobil’s major upstream oil and gas production projects and operations has been strengthened.