bluuebunny/crossref_metadata_2025_split huggingface dataset:
Carbonate Rock Typing Using NMR Data: A Case Study from Al Shaheen Field, Offshore Qatar
Authors: Frank Soren , Narayanan Ramdas , Hansen Pia , Allen David Furse , Albrechtsen Troels , Steinhardt Henriette , Raven Madeleine Julia , Fordham Edmund , Bize Emmanuel , Rose David Alan 
Published: February 2016

Abstract
Complex pore size distributions encountered in carbonate rocks have a large impact on the fluid flow characteristics of carbonate reservoirs. Consequently, although nuclear magnetic resonance (NMR) has been frequently used for characterization of clastic reservoirs, it has not been widely applied to carbonates. This paper describes a case study from the Shuaiba carbonate reservoir of the Al Shaheen field, offshore Qatar. Core data from a study well were used to establish an NMR carbonate rock-typing model for permeability estimation. The rock-typing model was verified in the study well with a wireline NMR logging tool.
Core analysis included thin-section petrography, NMR surface relaxivity, mercury injection, porosity and permeability measurements. NMR distributions determined on core were partitioned and linked to pore body size and pore throat size distributions. Several rock types were also defined based on their NMR and petrographic characteristics. To improve permeability prediction in the cored interval of the study well, an NMR-based permeability equation was derived.
The core-calibrated NMR carbonate rock typing model was applied to noncored sections of horizontal wells drilled in the Shuaiba formation having logging-while-drilling (LWD) NMR data to improve rock typing and permeability estimation, thus, providing valuable input data for reservoir modeling.

Introduction
Permeability estimation and rock typing of the complex Shuaiba carbonate reservoir in the Al Shaheen Field is an important element in the development of reliable petrophysical and geological models. Rose et al. demonstrated that facies changes along horizontal wells in the Shuaiba reservoir were captured by the T2 distribution from an LWD NMR tool. The corresponding permeability variation was linked to the facies, and a qualitative determination of the lateral permeability distribution was achieved.
Environmental Impact Assessment of Exploration Drilling in the South Caspian Sea
Authors: Tait R.D. , Parr T.D. , Germano J. , Maxon C.L. , Passmore J.L. 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Pre- and post-drilling environmental studies were conducted for two exploration wells drilled in the Azerbaijan sector of the south Caspian Sea. The two wells, located at water depths of 142 and 720 m, respectively, were drilled with water-based and synthetic-based drilling fluids. The studies were undertaken as part of the defined environmental, health, and safety management programs negotiated within the Production Sharing Agreements, and focused on surface sediments located within 1.2 km from each well. Post-drilling studies ranged from three months to three years following well completion. Co-located samples were analyzed for metals and hydrocarbons, including linear alphaolefins; and benthic community parameters, including species density, abundance, and biomass of major taxa. Eight months after drilling ceased, results for the well in 142m of water supported the Environmental Impact Assessment report, confirming that settled cuttings and muds were limited to400m distance, and that significant re-colonization of benthic infauna had occurred around the well site. Cross-sectional photographic images of the seafloor showed evidence of significant oxygen demand and settled cuttings within 50m of each well. Chemical and biological results for the well in 720mwater depth, sampled three months after well completion, are discussed in relation to the observed recovery processes.
More Than 30 Years Experience With F(P)SOs and Offloading Techniques
Authors: Lanquetin Bertrand 
Published: February 2016

Disclaimer
The information given in this paper is based on archives, interviews with people, etc. and is given to the best of our knowledge. There may be some minor inaccuracies on the dates and on the information given for which we would like to apologize in advance to the readers of this paper and to the providers of the equipment and installations mentioned here.

Abstract
TOTAL E&P Branch, present today in more than 43 countries and producing 2.6 Mboe/d, has steadily become an important player in the field of Floating (Production) Storage and Offloading facilities, key to several oil and gas field developments. The experience described below is the cumulated experience (upstream) from TOTAL, Petrofina and Elf Aquitaine who successfully merged in 1999 and 2000 to form TOTAL.
As the reader will rapidly notice this experience is extremely rich and diversified and includes many maiden installations as well as technology breakthroughs.
Some of them:–The Ifrikia (Ashtart field Tunisia 1973) was the first FSO (Floating Storage Unit, converted tanker) permanently moored by a rigid yoke on a CALM buoy, followed in 1978 by the Ifrikia II, the first purpose build FSO barge.–The Frigg flare (North Sea 1974) was the second Articulated Column. It followed an experimental articulated column installed in 1967 in the Bay of Biscay.–The first Ready Made Dolphin was installed on Quinfuquena (Angola 1979).–In the same year the first two turret type CALM buoys were installed on Mayumba (Gabon 1979), then Kole (Cameroon 1979).–Three CALM type buoys of a new design using self lubricating bushing in lieu of main roller bearing, were ordered for Rospomare (Italy 1981), ABK (U.A.E 1981) and Victoria field (Cameroon 1982).–The Licorne Pacifique converted tanker on Palanca field (Angola 1984) was the third CALM soft-yoke (the first one was in 1981).
How Clean is Clean? Is It Still a Debate?
Authors: Garland Emmanuel 
Published: February 2016

Abstract
Environmental Regulatory Framework for E&P activities has dramatically increased during the last decade, and no one contests that environment did benefit from the measures taken. But the development of the regulatory framework in many countries, the constraints it creates, raise the question on where the cursor should be fixed.
The latest developments of the regulatory framework show that:expectations from stakeholders increase, for all compartments of the environments, and everywhere in the world;the gap between constraints in countries with a long record of environmental regulations and the others is increasing;but countries which set up environmental regulations for the first time tend to take even tougher measures than the ones implemented in the countries with a long record of environmental regulations;the dialogue between stakeholders, competent authorities and E&P industry is worth the effort to promote it; it requires a change of perspective from all participants.
In that context, the debate on the ultimate goal(s) to pursue, and on the intermediates ones has usually been a source of misunderstanding between the regulators and industry, and it is only very recently that new, more pragmatic, ways to approach a common understanding of how clean is clean appeared, at the light of both the development of better monitoring or predictive tools and of the debate on zero discharge, zero harm to the environment.

Introduction
Environmental regulatory framework for Exploration and Production (E&P) activities has dramatically increased during the last decade. Not only western countries with long industrial record have set up tougher rules, some based on existing ones (e.g. the new requirements of the National Pollutant Discharge Elimination System – NPDES, in the US), others on new environmental approaches (e.g. OSPAR set of Decisions and Recommendations adopted between 1998 and 2001 which dramatically changed the way some environmental issues are dealt within the North Sea) (1–6), but countries with so far limited or no environmental framework have developed – or started to develop - environmental regulations, some of them with even tougher constraints than the ones enforced in western countries ones (e.g. Nigeria regulations on drilling fluids and disposal of drill cuttings).
A New Dawn for CO2 EOR
Authors: Espie Tony 
Published: February 2016

Abstract
A range of techniques have been developed to improve the recovery efficiency of oil reservoirs. Of these, gas injection is currently the second most common EOR process after thermal methods that is practiced on a material scale with some 250 mbd directly attributable. Initial exploration of gas injection focused on use of a hydrocarbon injectant. However, competitive sales markets for hydrocarbon gas led to the identification of CO2 as a potential injectant.
There is now over thirty years experience with the injection of CO2 for Enhanced Oil Recovery. Although initially developed as a means to improve oil recovery, there is renewed interest in the potential for CO2 EOR as an option to reduce global emissions of Greenhouse Gases. This may lead both to a significant expansion in the level of application as well as to some significant changes in the way in which CO2 EOR is applied.

Introduction
Many areas of the world are actively implementing gas injection to maximise the potential of extensive oil reserves. A successful gas flood requires two key criteria be satisfied. Firstly, the injected gas must be able to mobilise additional oil. Secondly, the flood must be able to sweep the mobilised oil to producers.
Additional oil may be mobilized in two ways. Firstly, gas may be able to access parts of the reservoir that have been bypassed by water. Second, gas may enable some incremental recovery from those parts of the reservoir already swept by water by virtue of the fact that the residual oil saturation to gas is usually somewhat lower than for water.
Many of the current gas injection schemes operate near to miscibility conditions to mobilise the maximum amount of incremental oil. The injected gas is often used in combination with water in order to get the joint benefits of mobilising oil with the miscible gas while using water to sweep mobilized oil to producing wells.
CO2 Capture and Storage: Contributing to Sustainable World Growth
Authors: Espie A.A. 
Published: February 2016

Abstract
The potential to exacerbate or accelerate climate change as a consequence of burning fossil fuels has received considerable international attention in recent years. The Kyoto Protocol emerged as one response to initiate first steps towards stabilisation of atmospheric concentrations of CO2.It is clear that there is no one single technology that can lead to stabilisation in the timeframe that appears to be required. Large-scale implementation of capture and storage of CO2 is being considered as a potential option that could make a material contribution to a portfolio of options for the stabilisation of atmospheric concentrations.
A number of hurdles require to be overcome before this technology will be widely applied. These include i) significant reductions in the cost of capture of CO2 from combustion processes, ii) acceptance that geological storage can be a safe and effective mitigation option, iii) the development of commercial mechanisms that enable viable projects to emerge and iv) clarification of a number of regulatory and legal issues.

Introduction
The Intergovernmental Panel on Climate Change (IPCC) was jointly established in 1988, by the World Meteorological Organization (WMO) and the United Nations Environment Programme (UNEP). Its present terms of reference are to:Assess available information on the science, the impacts, and the economics of - and the options for mitigating and/ or adapting to - climate change.To provide, on request, scientific/technical/socio-economic advice to the Conference of the Parties (COP) to the United Nations Framework Convention on Climate Change (UNFCCC).
The Third Assessment Report from the IPCC [1] was published in 2001.This detailed review of the scientific, technical and socio-economic aspects of climate change concluded that there is clear evidence to show that global climate has changed over the last 100 years and that a significant proportion of that change could be attributed to the release of anthropogenic CO2 into the atmosphere during the combustion of fossil fuels.
Project Financing of Qatargas II
Authors: Fleming A. , Minyard R.J. 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
In December 2004, the Qatargas II joint venture between Qatar Petroleum(70%) and ExxonMobil (30%) completed the —7.6 billion financing for the integrated project to supply LNG from Qatar to the United Kingdom.
The landmark financing, involving 57 lenders, is the largest ever energy project financing. It provided the funds to execute the complex project which involves the development of offshore wells, production platforms, pipelines and natural gas liquefaction facilities in Qatar; construction of the South Hookimport terminal at Milford Haven in South Wales; and the sales and marketing of the gas by the winter of 2007/8. The financings, which set several new benchmarks in their pricing and other terms, also mark a number of firsts in energy industry project financing. These include:–The first LNG financing where the entire chain from wellhead to terminal has been developed by the same partners throughout and funded through integrated financings.–The largest long-term Islamic project financing.–At 25 years, the South Hook Terminal financing is the longest sterling bank energy transaction without government or mono-line credit support.
The presentation will cover some of the key elements that resulted in the award winning financing including the:–The challenge of financing the entire value chain from wellhead to terminal–Early development of successful Standard Financing Conditions (TermSheet)–Importance of coordinating project agreements and financial agreements–Structuring for future business flexibility–Market reception for Qatar project debt
Portable Test Separator (SEPARATRUCK) Alternative of Measurement
Authors: Ruiz M.A. , Arditi L. 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Exact and reliable production well testing allows to quantify the volumes of fluids produced and additionally to diagnose the anomalies on time to carry out early adjustments in the wells, in order to have a production with the highest efficiency. The Portable Test Separator SEPARATRUCK appears like an economic alternative of measurement in wells production in the Venezuela's Orinoco Heavy Oil Belt. The project consisted on the elaboration of a design methodology, based on studies made in the field that allowed determination of the main faults in the measurement of the production with the traditional test equipments, establishing specific considerations for the design of a new, portable and automated in all its functions measurement equipment. The mass, is the primary unit of measurement and because it is not affected by the changes of viscosity, density, electrical conductivity, pressure and temperature; this parameter turns out to be simplest and at the moment most reliable to measure. For that reason, the prototype will be equipped with two mass flow and density meters, in addition to a radar device able to control different fluid levels configurations; this, in combination with technological improvements of the Coriolis measurers, will provide a wide rank of ability allowing to adapt the configuration of the system, resulting in an equipment able to test wells that produce from different reservoirs (different API gravities) and at variable production rates (different GOR), diversifying the measurement, making flexible and popularizing the equipment. The design calculations were validated by means of numerical simulation, obtaining a portable test separator able to handle upto 2,500 bbl diluted heavy petroleum, with water cuts between 0 and 100%, and a maximum gas rate of approximately 5 MMscfd.
Technology Deployment Model
Authors: Al Wardi Ali , Al Murshidi Abdulsattar Mohd , Edwards Clement 
Published: February 2016

Abstract
A recent health check analysis indicated that a better structure was required to deploy new technology in the company. An Opportunity Framing workshop was held in May 2004 and a team was formed to formulate a new technology deployment model.
The model developed, uses a network of technology passionate individuals organised into Technology Focus Groups (TFG). These groups are multi-function/cross-asset and have members from the Function and the Line. They will be the implementation arm of PDO's technology process. The model also calls for a multi functional leadership group to provide support and nurturing to TFG's as well to act as a decision making body.
The essence of this model is to maintain a balance between the pull and push of Technology. It improves the ability to make decisions, accelerate or stop deployment and redeploy resources accordingly.

Introduction
Roadmapping is a technique that is used by many companies and research organizations to plan for the future. Motorola found that when group of people in the company come together to develop a consensus vision for the future of technology areas that affected their business, this pervasive culture of technology roadmapping enabled them to produce roadmaps that communicate vision, attract resources from business, stimulate investigations and monitor progress.
Opportunity framing or realization process is a powerful and structured approach for defining and understanding an opportunity, it ensures planning the road to success. It facilitates a true dialogue among Opportunity team to disuses several, distinctly different perspectives of the:
Opportunity ("Where are we now?"), definition of its success at several future milestones ("Where do we want to be?") and the different decisions and processes that need to be set to realize the opportunity ("How are we going to get there?")
Some Practical Issues on Real-Time Reservoir Model Updating Using Ensemble Kalman Filter
Authors: Wen Xian-Huan , Chen Wen H. 
Published: February 2016

Abstract
The concept of 'closed-loop' reservoir management is currently receiving considerable attention in the petroleum industry. A 'real-time' or 'continuous' reservoir model updating technique is a critical component for the feasible application of any closed-loop reservoir management process. This technique should be able to rapidly and continuously update reservoir models assimilating the up-to-date measured production data so that the performance predictions and the associated uncertainty are up-to-date for optimization calculations. The ensemble Kalman filter (EnKF) method has been shown to be quite efficient for this purpose in large-scale non-linear systems.
Previous studies show that a relatively large ensemble size is required for EnKF to reliably assess the uncertainty and a conforming step is recommended to ensure the consistency between the updated static and dynamic variables. In this paper, we further explore the capability of EnKF focusing on practical application issues including the correction of the linear assumption during Kalman updating with iteration, the reduction of ensemble size with a simple uniform re-sampling scheme, and the impact of assimilation time interval.
Results from this paper demonstrate that the predictive capability of the updated models can be considerably improved when iteration is used within the EnKF updating. The use of iteration reduces the impact of nonlinearity and non-Gaussianity. However, iteration is required only when predictions are very different from the observed data. We also show that a simple uniform re-sampling scheme can significantly reduce the ensemble size necessary for reliable assessment of uncertainty, in addition to improving accuracy compared to the traditional random sampling method. Finally, we show that the non-iterative EnKF is sensitive to the size of time interval between the assimilation steps. Using the iterative EnKF, results are more stable and more accurate reservoir models and predictions can be obtained even when a large time interval is used during the assimilation. This indicates again that iteration within the EnKF updating serves as a process that corrects the non-linear and non-Gaussian behaviors.
Integrated Geochemical and Basin Modeling Analysis of the Jurassic and Cretaceous Hanifa Hydrocarbon Systems in Qatar
Authors: Guthrie John , Maze William J. , Al-Emadi Ismail Abdullah , Zahran Mamdouh E. 
Published: February 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Organic-rich mudstones of the Tuwaiq Mountain and Hanifa Formations of the Jurassic Hanifa Supersequence are the major source rocks for much of the oil in the Arabian Gulf. An integrated geochemistry and basin-modeling study on these source rocks and their oils was conducted to explain the distribution of petroleum accumulations within the Hanifa hydrocarbon systems of Qatar.
Principal component analysis (PCA) of biomarker and stable carbon isotope data for oils and condensates delineates three major hydrocarbon systems in Qatar: Jurassic Hanifa-sourced oils,Cretaceous Shilaif-sourced oils and,Silurian Qusaiba-sourced condensates (Figure 1).
The biggest contribution to the PCA comes from Factor 1 where 63% of the variance in the data is primarily due to source rock facies variations. Oil-to-oil correlations indicate that the Jurassic Hanifa-sourced oils are present in both Jurassic and Cretaceous reservoirs.
The Hanifa sourced-oils exhibit relative thermal maturity differences between fields and by reservoir age (Figure 2). In general, reservoired-oils(Arab C, Arab D, Araej, Izhara, and Uwainat reservoirs) from the Dukhan, Maydan Mahzam, and Bul Hanine fields have higher relative thermal maturities than reservoired-oils from Al Rayyan, Al Shaheen, and Idd El Shargi. For a particular field, the relative thermal maturity of the oil appears to be related to stratigraphy, with the least mature oil in the youngest reservoir, and oil maturity increasing with reservoir depth. This is best observed in the Idd El Shargi field where the oil is least mature in the Cretaceous Shuaiba and Jurassic Arab C reservoirs and becomes more mature in the older (deeper) Arab Dand Uwainat reservoirs (Figure 2).
The occurrence of relatively higher maturity oils in deeper reservoirs (ArabD, Uwainat, Izhara) suggests that the reservoirs were filled from top tobottom. Figure 4 shows that in the Eastern Salt Province fields, the Hanifa source rock maturity increased from early mature to peak mature since50Ma. During this time, the deeper Izhara and Uwainat reservoirs of the EasternSalt Province fields were charged with higher maturity oils.