bluuebunny/crossref_metadata_2025_split huggingface dataset:
TOTAL E&P Consideration of new Technologies in Rotating Machines to Respond to the Requirements of Future O&G Developments
Authors: QUOIX Bernard , GELIN Alain 
Published: May 2016

Extended abstract

Introduction
To respond to ever more demanding and critical requirements dictated by the current and future developments of O&G fields, combined with harsher environmental conditions, TOTAL consider that innovation and introduction of new technologies are today unavoidable, and this is particularly true for rotating machines. Some examples to illustrate this tendency can be listed, such as:Reinjection pressures in the reservoir ever increasing, reaching 700 bar and more,Gas flows increasing and thus requiring more and more power,Ever increasing water depth: Today, it is almost ordinary to install multiphase pumps and soon high boost multiphase pumps and compressors at minus 1,500 meters of water depth and soon deeper,Less complex compression shaft lines (high speed motors, oil free, Active Magnetic Bearings, sealless), no HC emissions, for upstream applications,Remote Monitoring and Diagnosis,Harsher environment conditions (Artic, large ambient temperature range, offshore, corrosive contaminants, salts, sand, harmattan, etc.), isolated production sites,Wet gas with CO2 and H2S with selection of appropriate metallurgy,More viscous fluids to be pumped in multiphase conditions from the sea bed,Very large gas turbines for future all electric FPSOs and floating production facilities (LNG).
And of course all these new technologies are developed with the requirement of limiting CO2 and NOx emissions, increasing energy efficiency, and improving equipment reliability, while preserving safety of the people and the machines.
The famous "two machines two years" criterion which uses to be the golden rule in the past among most of the Majors is no longer applicable and thus superseded as conditions of new O&G developments, whether climatic, environmental, reservoirs, technological, are changing very rapidly. Therefore, TOTAL, have implemented a thorough qualification process to introduce innovations, allowing thus to lead the required technological evolution, to cope with the rapid market changes, to be able to respond to more and more complex projects, to be ready to implement these new technologies whenever required, reducing costs and increasing energy efficiency, while minimizing the associated risks.
The paper provides some examples of implementation of such new technologies in rotating equipment and describes the qualification process that is followed to declare these technologies fit for purpose.
Implementation of Real Time Geosteering to optimize horizontal drilling, greater Burgan field
Authors: Al-Zuabi Abdullah , Bahman Hussain , Al Zankawi Omran , Kotecha Rohit , Mereno Beltran , Mukherjee Pradeep , Mudavakkat Anandan , Al-Sabea Salem , Al-Hamoud Jamal 
Published: May 2016

Abstract
With increasing complexity to tap oil in clastic reservoirs due to stratigraphy, structure and facies variation optimization of placement of horizontal well has become a key to success. To augment this aspect Kuwait Oil Company (KOC) has established Geosteering Centre which has become the hub for decision making while the well is getting drilled for landing at top of reservoir or lateral is being drilled.
The Great Burgan field located in South East Kuwait asset of KOC major Horizontal drilling campaign started in 2005 mostly in clastic reservoirs.. This field been on the production since 70 years, most of its development wells were drilled and completed as vertical or deviated. It was decided to utilize horizontal well technology to drill thin productive layers. This paper illustrates an integrated approach using 3D-Model along with seismic analysis, knowledge sharing and most advanced Geosteering technology to successfully transfer, edit, and interpret the dynamic data in real time to monitor the drilling progress specially the lateral section. This state-of-the-art computing and visualization technology enables geologists to take corrective measures keeping the well in sweet zone as much as possible, through direct satellite communication with the rig's Geosteering unit and planned well course VS actual trajectory was continually updated and well path corrected based on information received.
The Geosteer center moved Field Development South-East Kuwait to a whole new level of collaboration that is equipped with latest in visualization, communication and computer technology in order to properly place and geologically navigate one of the world's largest siliciclastic reservoirs.
Today the interactive process of geosteering, using real-time data and making real-time decision has resulted in mitigating inherent geological risk in order to optimize the best drilling results for each horizontal well and to ensure an effective implementation of all new ongoing field development plans and made it possible to tackle thin reservoirs which now can be drilled economically.

Introduction
Kuwait oil Company initiated horizontal drilling approach since early 1990's, and to place the wells successfully in the desired reservoir, an integrated approach using static model and subsurface analysis, knowledge sharing, effective communications and state of the art geosteering technology have all been utilized in order to have a successful well placement.
Gas Oil Ratio (GOR) Estimation Using Downhole and Surface Well Sensors
Authors: Al Muailu Husain Al , Al Khelaiwi Faisal , Al Fakher Ahmad 
Published: May 2016

Abstract
As the concept of intelligent fields mature, field operators expand on the installation and utilization of downhole instrumentation in a quest for higher oil and gas recovery and net present value. Permanent downhole monitoring systems (PDHMS) are some of the intelligent field implementation enablers, which provide continuous monitoring and surveillance of wellbore/reservoir performance in addition to their recognized operational safety enhancement through elimination of well intervention operations for data acquisition. The advanced analysis of the data provided by this equipment forms the key to unlocking their full utilization potential and recognizing the value of the information that they provide.
A remote field located in Saudi Arabia commenced its production from a thin oil column lying between a large gas-cap and a water aquifer. The gas-cap gas breakthrough and production from the producing wells have increased gradually; resulting in an increase in the wells gas-oil ratio (GOR) from an average of 880 standard cubic ft/stock tank barrel (SCF/STB) at the start of the field production to 1,536 SCF/STB. The production of these wells is currently controlled using the surface and subsurface control valves to maintain the gas production and GOR at acceptable levels.
The wells connected to rate testing facilities are delivering non-accurate gas rate measurements because of frequent malfunctioning in the Coriolis meters. This problem is being mitigated in several fronts such as replacing the testing facilities; however, a method to estimate the GOR in the wells is needed until all the old testing facilities are replaced.
An innovative technique to identify the onset of gas-cap-gas production and estimate its value using the downhole sensors has been developed to provide early notification of the free gas breakthrough and improve its control. This technique can provide an estimation of the wells' GORs and can be used as a validation method to the testing facility GOR measurements.
This paper proposes an approach to estimate the GOR using Matlab code that helps in the calculation of the pressure drop between the PDHMS and matching it with the actual readings at the estimated GOR. This technique was tested on three wells with healthy rate and PDHMS information.
Transforming Seismic Reflection Data Into Quantitative Rock Properties by Seismic Inversion
Authors: Rajput Sanjeev 
Published: May 2016

Abstract
The transformation of seismic reflection data into quantitative rock properties can be very valuable in all phases of oil and gas exploration and production. In this study, public domain data from Australian offshore have been used to explain the logical workflow, which consists of systematic steps from seismic petrophysics to rock physics modeling and seismic inversion for quantitative rock property estimation.
The application of seismic inversion technology offers many rewards, such as: better reservoir definition and management; better resource estimation; and reductions in uncertainty. The main benefit is that it improves direct and intangible interpretation of seismic data to provide meaningful geological boundaries in the subsurface.
In order to provide the reliable estimate of rock properties for reservoir modeling the workflow is tested rigorously and divided into three categories which are based on the basic inversion types. The results reveal that relative impedance inversion should be performed first, which then followed by revision of seismic interpretation on impedance data. Full bandwidth rock properties are estimated by deterministic inversion. The results can be improved by several iterations of well to seismic tie, wavelet estimation, and low frequency models. As resolution with accuracy has always been challenging, the stochastic inversion approach is trailered for reservoir characterization and high resolution rock properties have been predicted. This produces a number of possible rock property models, as well as litho facies models and the results can be optionally constrained by the well data. It can be concluded that, to some degree, stochastic inversion is able to overcome the limited seismic bandwidth by integrating the rock physics properties of different lithologies. The examples of seismic inversion are discussed to demonstrate the significant benefits can be obtained by following an optimized workflow that is tailored to deal with the uncertainties that impact the end product.

Introduction
Seismic surveys are routinely performed to gather information about the geology of hydrocarbon fields. Seismic data, even when it has relatively low resolutions, can still deliver a structural model for the reservoir. The availability and coverage area of the data provides valuable information to constrain the reservoir model. Geophysicists are now able to extract greater quantitative information about reservoir rocks and fluid parameters from seismic data by working backwards using seismic inversion methods. Described as the flip-side of forward modeling, seismic inversion is the process of characterizing rocks and fluids that have produced the seismic data. In a sense, the process involves trying to determine the input (rock properties) by looking at the output (seismic data). It starts with actual measured data, removes the wavelet and derives acoustic impedance from reflection coefficient (Figure-1) with a low frequency model to infer rock properties and deliver earth model.
Basin-scale Simulators For De-risking Of Unconventional Play-types: A Practical Approach To Enable In-time Decision Support.
Authors: Keym Matthias , Meuric Olivier , Kuhn Philipp , Buerger Claudius , Dieckmann Volker , Podlaha Olaf , Senior William 
Published: May 2016

Introduction
Unconventional resources have emerged as an important part of the world's energy supply. Engineering technological advances such as drilling horizontal clusters and completion solutions like hydraulic fracturing have contributed to the exponential growth of unconventional opportunities and their exploitation. Still a lot of headroom is left for a deep and improved understanding of the subsurface geologic controls on hydrocarbons' fluid movement and trapping characteristics. These characteristics are becoming paramount to de-risk the presence and extent of producible hydrocarbons in current and upcoming resource play opportunities.

Unconventional Basin Simulator technology
More specifically, it is the actual migration path and the compositional changes and alteration processes along it, which require an increase in focus. The latter seems to show a bigger impact than the initial question of whether a particular trap or reservoir was charged.
Applying 3D Close the Loop and Probabilistic Seismic Inversion Techniques on the Tibr Asset in Petroleum Development Oman
Authors: Scholten-Vissinga Marianne , Chockalingam Chuck , Tiller Gottfried M 
Published: May 2016

Abstract
In Petroleum Development Oman (PDO), a seismic driven 3D Close the Loop workflow has been successfully applied for the first time to the Tibr asset. The business objective was to delineate channel sands with challenging rock properties at a relatively deep target by better predicting the distribution of sands and shales within the Upper Gharif and Al Khlata reservoir sequences. As a result, we were able to reduce subsurface uncertainties leading to improved reserve estimates.
3D Close the Loop workflows allow for better predictions of layer thickness, reservoir properties and velocity away from the wellbore by optimal integration of seismic amplitudes with all other reservoir data. A pre-existing static reservoir model describing reservoir properties through geo-statistical algorithms served as main input. Rock and fluid property models were derived from existing well data. By relating reservoir properties such as net-to-gross, porosity and hydrocarbon saturation to acoustic properties, the 3D models were converted to a synthetic seismic volume, which could then be compared to measured seismic data. In the final stochastic inversion, reservoir properties were updated until synthetic and seismic data matched within an acceptable error range defined by the signal to noise ratio.
Optimizing Reservoir Testing Operations With Downhole Wireless Telemetry System
Authors: Acar Cagdas , Aljifri Abdullah , Bekkouche Yassine , Maalej Mohamed , Nwagbogu Ifeanyi , Vannuffelen Stephane 
Published: May 2016

Abstract
A new wireless telemetry system has been field tested in a variety of conditions in Middle East with excellent reliability. This wireless system enables bidirectional communication between the surface and downhole tools during testing operations by using acoustic signal. The wireless telemetry is used to transmit bottomhole pressure and temperature to the surface and permits control of downhole tools. This paper will describe the operating principle of the wireless system, present examples of how this system has been used to optimize the testing operations and summarize the key benefits achieved. The real time downhole data, compared with memory data has shown good match, has been streamed to client office successfully in real time, realized benefits from the operation and reservoir aspects for a vertical deep offshore well: Efficient management of wellbore events; providing operational awareness about tools status; refining the test sequences in real time, verifying underbalanced prior to perforation, monitoring stimulation pressures at sandface to avoid fracturing, updating the reservoir interpretation in real-time, optimizing the duration of flowing well sequences (clean up) and verifying the achievement of test objectives prior to retrieving DST string.

Introduction
Exploratory well testing to evaluate hydrocarbon bearing zones in new fields is normally performed with a drilling rig on location. The main objective of exploration well testing is to capture representative data on the reservoir and fluids by acquiring surface and downhole measurements in optimum time and cost manner. Wireless telemetry system that can transmit data from the bottom hole to the surface instead of solely relying on surface data and waiting for downhole sensor retrieval at the end of the test enables achieving this objective.
There are some systems in use in the industry while they are far from the efficiency due to following reasons: 1- Wireless System providers and overall downhole testing operations providers are different that usually brings the integration of the service issues 2- The Wireless System providers lack of the testing operation sequence and data flow 3- Wireless system providers do not have the testing real time capability and domain expertise that can upgrade the service level to solution level 4- The Available wireless telemetry systems within the main testing service providers has been limited to certain environments. Onshore and Low noise environments.
Step Change In Shallow Water Reflection Seismic By Advances In De-multiple Techniques
Authors: Roende H. , Huegen C. , Madsen L. , Emang M. I. , Halliday S. , Henderson J. R. 
Published: May 2016

Abstract
A high-resolution survey with a total of 2300 km2 of 3D reflection seismic data was acquired over the Al Shaheen Field, Block 5, offshore Qatar, from October 2006 to April 2007. Reverberations from the hard shallow water bottom and other types of noise limited the value of the original processing. Re-processing using new technologies has produced a step change in quality resulting in cleaner images for interpretation and superior angle stacks for inversion.
The multiples were removed by applying an enhanced processing workflow based on a predictive, data-driven algorithm. The workflow involved attenuating short-period water-layer related multiples - a process that is referred to as shallow water demultiple (SWD). The SWD method makes use of water-layer multiples in the data to reconstruct the missing water-bottom primary reflection, and then uses the reflection for predicting these shallow multiples. The method takes into account the spatial varying nature of the subsurface. Since the multiple model predicted by SWD has similar amplitude and phase as the input data, very short matching filters can be utilised in the adaptive subtraction process.
These processing improvements have influenced a broad spectrum of interpretations such as better structural representation including fault mapping and improved understanding of facies. In conclusion, detailed and careful testing has resulted in new added value from this large high resolution 3D data set by applying technologies that were not available when the data was acquired and processed in 2006–2008.

Introduction
Reflection seismic data is a primary tool for mapping the subsurface, structure and sedimentary facies and if the amplitudes are reliable, then also potentially lithology and fluid effects. The seismic signal is composed of the direct interface response, but is often contaminated by noise arising from multiples, scatter and mode conversions. This noise can make it difficult to interpret and analyse the seismic data. This paper presents a case study where an integrated approach between processing specialists and interpreters has successfully been adopted during the re-processing of a large 3D survey (2300 km2) acquired in 2006 and 2007 and where new technologies and workflows have made a step change in the quality of the 3D migrated cube. Demultiple, acquisition footprint removal and streamer/OBC merge have been improved to produce a volume that can be interpreted with higher confidence.
Reducing Drilling Risk using Look-ahead VSP – A Success Case Study for Carbonate Exploration Well, Offshore Vietnam
Authors: Nguyen Dac The , Sanders Michael , Millot Pascal , Rehman Sadu Ur , Jones Michael , Oo Aung Than , Golding Christopher James , Aquilina Giovanni , Fichera Rosario 
Published: May 2016

Abstract
The accurate prediction of the depth of top carbonate while drilling carbonate reservoirs is important to avoid losses and well control problems. This can have a significant financial impact. This paper demonstrates the use of innovative look-ahead VSP technology in Vietnam to refine depth prediction of the top of carbonate ahead of the bit for accurate geo-stopping.
An offshore exploration well was being drilled in an area with drilling challenges. This was the first well in the field and lacked offset well velocity information, so there was a high degree of depth uncertainty to the top of the carbonate target from surface seismic interpretations, making drilling operations risky. An intermediate VSP was requested to look for reflections ahead of the intermediate TD using Schlumberger VSI1 tool. The VSP data was acquired in open and cased hole using an air gun cluster as the seismic source.
The drilling program required the casing to be set immediately above the top of the carbonate. By acquiring an intermediate VSP, the depth uncertainty was reduced and the target depth prediction was refined. This was achieved using the look-ahead VSP technique, from which the acoustic impedance and velocity ahead of the bit was estimated. This was combined with time-depth from the VSP data over the logged interval to help refine the predicted depth to the top of the carbonate. This was used to optimize the depth at which the casing was set. The error range for the top carbonate depth from the surface seismic interpretation was +/-50m. The final prediction depth from the VSP interpretation is 6m shallower than the actual carbonate reservoir.
Guided by the inverted acoustic impedance log and velocity ahead of the bit from look-ahead VSP, a further 100m was safely drilled before setting the casing. The casing point was set successfully without penetrating the carbonate. The intermediate VSP results helped to decide drilling ahead in a safe manner with confidence, after setting the casing before penetrating the carbonate target.
Integrated Formation Evaluation Delivers an Optimum Exploitation Strategy in a Tight Sand Play, Offshore China
Authors: Shi R , Wang J , Zhang Guo Dong , Cai J , Tellapaneni Prasanna Kumar , Xian Chenggang , Chen Jichao , Yu Y 
Published: May 2016

Abstract
With increasing focus on exploration in tight and low-permeability environs, formation evaluation today has become more challenging. Integrating all measurements and understanding and evaluating uncertainties are critical for an effective evaluation workflow. Such a workflow should deliver the productivity and completion strategy for an effective exploitation of reserves. The field under study is an exploratory field located in the East China Sea, and the play is an anticline along a north-south axis. The main zone of interest is in a giant sandstone formation with very low porosity. Since this is a potentially large accumulation, it was necessary to produce gas to surface to confirm the discovery and book reserves.
In this study, an effective Reservoir Quality (RQ), Completion Quality (CQ) workflow is developed and executed to address the formation evaluation objectives in challenging environments. Integrating core measurements with petrophysical evaluation leads to an effective estimate of the petro physical properties and a quantitative estimate of the uncertainties involved. These uncertainties are then taken forward into a reservoir model to estimate the productivity from these sands. Geomechanical analysis is done to evaluate various completion options including hydraulic fracturing and an estimate of the post-fracturing productivity is evaluated for various fracturing scenarios. With this evaluation, an informed decision on the best way to exploit reserves was made. We present this study as an example of how various formation evaluation measurements can be integrated into a well deliverability workflow in a tight gas reservoir.

Introduction
The East China shelf basin offshore China is shown in Fig. 1. Although exploration has been ongoing in this basin since the early 1980s with some discoveries, mainly in the Chunxiao and Longjing structures (Jia and Ma 2000), given the size and complexity of the basin, exploration in this basin is still ongoing.