bluuebunny/crossref_metadata_2025_split huggingface dataset:
Estimation of Relative Permeability using the Lattice Boltzmann Method for Fluid Flows in a Cretaceous Formation, Abu Dhabi
Authors: Grader Avrami , Mu Yaoming , Toelke Jonas , Baldwin Chuck , Fang Qian , Carpio Gustavo , Stenger Bruno , Al Dayyani Taha , Kalam Zubair 
Published: February 2011

Abstract
A set of Petrophysical properties including porosities, absolute permeabilities, resistivity indices, elastic properties and Archie’s cementation exponent "m" were determined for a number of carbonate core plugs representing four common reservoir rock types (RRTs) of the a Cretaceous Formation Abu Dhabi. The same core plugs were then used to estimate SCAL properties including water-oil relative permeabilities using digital rock physics (DRP). DRP is referred to in this paper as the combination of advanced 3D imaging techniques such as X-ray computed tomography (CT) scanning, and the use of the Lattice Boltzmann Method (LBM) for fluid flow modeling.
The plugs were scanned, using X-ray Computed Tomography (CT), at several scales to establish the distribution of macro- and micro-porosity fractions of the carbonate samples, and identify the primary flow units. Comparison of direct measurement results with the LBM-based modeling was used as a validation of its practical ability to predict two-phase flow properties for carbonates for carbonates. Results of this study indicated that the LBM-based method achieved a good to reasonable prediction for several reservoir characterization properties such as residual fluid saturations. Some deviations were present and discussed. Finally, an up-scaling process for determining water-oil relative permeabilities for a carbonate sample exhibiting a bimodal porosity distribution was presented using one of the cores in the study as an example.
Meeting the Challenges in Developing a Mega-Field with Electrical Submersible Pumps
Authors: Al-Ali Mohammed , Warsi Syed A. , Al-Arnaout Ibrahim 
Published: February 2011

Abstract
Saudi Aramco is famous for making history in the oil industry; the recent jewel in the crown is the state-of-the-art development of intelligent fields with electrical submersible pumps (ESPs).
The commitment of developing the world’s largest oil increment development in history is itself a challenge. This challenge becomes enormous, if the field is to be produced using ESPs.
The challenges evolved everything from ensuring the reliability of the ESP equipment, handling half a dozen ESP installations at a time, applying consistent installation standards across all ESP installations and maintaining high installation quality for all wells. The wells are completed with downhole sensors and the state-of-the-art supervisory control and data acquisition (SCADA) system, which has the capability to remotely operate the ESPs. In this regard, one of the challenges was to ensure equipment integrity while opening and closing the wells remotely. Developing the required work force to handle the installations and subsequently optimizing the ESP performance was another huge challenge.
This paper presents how Saudi Aramco took up to these challenges and completed the field before the target date with the best ESP installation results. The post commissioning ESP failure rate in one year is the best record in the company.
Optimization and Design of Carbon Dioxide Flooding
Authors: Odi Uchenna , Gupta Anuj 
Published: February 2011

Abstract
Increasing energy demand coupled with public concern for the environment has placed the oil industry in an awkward position as profit-making energy provider and protector of the environmental. Today fossil fuels are the most efficient at meeting the global energy needs but have the undesirable outcome of potentially harming the environment due to production of carbon dioxide. Carbon dioxide flooding of oil reservoirs is a proven method for increasing oil production by using the miscible interactions between reservoir oil and carbon dioxide. Carbon dioxide flooding is beneficial to the environment and to petroleum producers because it uses the harmful carbon dioxide as the main agent to increase oil production. The main challenge in using this technology is applying laboratory data to its design and optimization.
The objective of this work is to develop a strategy for applying laboratory data to the design and optimization of carbon dioxide flooding process. To accomplish this, reservoir simulation studies were conducted based on carbon dioxide laboratory data. Carbon dioxide laboratory core flood results were studied and modeled using a reservoir simulator. Once there was a match between laboratory data and core flood simulations the results were used to simulate field scaled carbon dioxide flooding.
Results of these simulation studies were used to perform optimization using adjoint based algorithms and non adjoint based algorithms. Adjoint based optimization algorithms require access to simulator code while non adjoint based algorithms do not require access to simulator code. A comparison of both methods is predented in this work to show their advantages and disadvantages. This work will address best practices in applying laboratory data to simulation and optimization studies.
The work-flow presented in this work can be used to design and optimize field carbon dioxide floods. These results will serve as a basic guideline in applying laboratory data to full field carbon dioxide flood optimization.
Techno-Economic Modeling & Conceptual Design Optimization of CCS Facilities using Value Engineering & Multi-Objective Stochastic Algorithm
Authors: Mossolly Mounir 
Published: February 2011

Abstract
Profound scientific insight into the carbon cycle and deeper understanding of the potential consequences associated with risks of climate change, along with a recognized public awareness about the link between global warming and human activity, has put the issue of finding and approving mitigation actions in the top national & international agendas. On the other hand, the ever increasing need of energy; necessary for economic growth, and the expected strategical reliance on fossil fuels and coal as a major energy source in the foreseeable future, will definitely lead to a dramatic increase in carbon generation. Eventually, an effective mitigating action can only be achieved by capturing the carbon release, or emission, to atmosphere rather than by cutting-down carbon generation. Even though the full scale deployment of integrated CCS facilities is still immature, yet it is very promising. The technical feasibility of the component technologies has been proven successful. Applications such as Carbon Capture in large ammonia plants, CO2 transportation via pipelines and transport ships and Carbon injection for Enhanced Oil Recovery (EOR) are already in operation. The real challenge for constructing & operating CCS facilities is financial & political rather than technical. Huge investments are required globally on a large scale and need to be economically and socially justified. It is estimated that building an associated Carbon Capturing facility along with a Power Generation plant may double the capital cost and increase the running cost up to 1.5 times, as a consequence it is thought that the price of electric power to be paid by the end-users will increase by at least 50%. This economic “penalty”, sensed at the short term, will raise serious public concerns. Thus there is an urgent need to find feasible financial models for deploying CCS technology with the minimum cost possible. Such a task requires the design optimization of CCS facilities based on techno-economic models. Techno-economic models based on mathematical formulation for the partial components of CCS facilities are readily available in the literature, but still there is a necessity to integrate these component models together in a one analytical model to view the picture as a whole, after all, the complete CCS train will be operating synchronously as one train entity. Once such an integrated model is available, an optimization problem can be formulated, and a technically feasible and financially attractive solution can be found to achieve the minimum total cost with the optimum design variables. Cutting down costs will be enhanced with time, following the trend of the learning curve in this field. This paper presents a methodology for implementing design optimization of CCS facilities at the conceptual level by simulating various combinatory scenarios, for finding the most economically attractive & technically feasible solution.
Development of Structural Regional Acceptance Criteria for Existing Fixed Offshore Structures in the Arabian Gulf
Authors: Yasser Mohammed 
Published: February 2011

Abstract
The Joint Industry Project (JIP) is a worldwide project that concerns the development of guidance in the form of a draft API Recommended Practice (API RP2 SIM) that addresses SIM (Structures Integrity Management) issues for existing fixed steel offshore structures around the world. It also concerns the Preparation of a methodology that can be used to provide a consistent minimum reliability (against environmental overload) for offshore platforms located in different regions around the world and which is referred to as Regional Acceptance Criteria (RAC).
As a member participant in the JIP, ADMA-OPCO took the initiative to develop the Arabian Gulf Regional Acceptance Criteria (RAC). A number of structures were selected for the study representative for the range of structural types and robustness across the fleet of structures composed of about 277 platforms. It involved performing structural pushover analyses for the selected structures and reliability analysis, the work involved determination of the target structural reliability, which equates to an acceptable probability of failure (PF) which is typically a function of the consequence of failure of the platform. The maximum acceptable annual failure probabilities for HIGH, MEDIUM and LOW consequences of failure categories of the whole fleet were determined.
The above target PF’s were converted into equivalent RSRs (reserve Strength Ratios) and dead load factors as a RAC.
Summary of Environmental Issues, Mitigation Strategies, and Regulatory Challenges Associated With Shale Gas Development in the United States and Applicability to Development and Operations in Canada
Authors: Arthur J. Daniel , Coughlin B. J. , Bohm B. K. 
Published: February 2011

Abstract
This paper will summarize key environmental and regulatory issues associated with Shale Gas development in major shale plays in the United States, actions taken by environmental non-governmental organizations, government, and industry on these issues (including mitigation strategies). Further, the paper will present the current and future pictures of these issues and the applicability of these issues to Shale Gas development in Canada.
Unconventional Resource Development and the Role of the Regulator
Authors: Eynon G. , Hill C. , Goodman T. 
Published: February 2011

Abstract
Alberta's Energy Resources Conservation Board (ERCB) has regulated oil and gas resource development for almost 75 years. Throughout most of that time the industry and the regulator were concerned with conventional oil and gas resources. In the last decade or so the emphasis has shifted, for several reasons, towards unconventional resources—in situ bitumen, tight oil, tight gas, deep- or basin-centred gas, coalbed methane (CBM), shale gas, and in situ coal gasification.
The characteristics of these resources, as well as the technologies required to develop them, create the need to modify the ERCB's regulatory framework. This is integral to reaching the ERCB's vision of being The Best NonConventional Regulator in the World, capable of dealing with the pressing issues of the future energy development in Alberta. Given the realities of the changing resource base, unconventional resources are a priority, and the ERCB needs to adopt non-conventional ways of regulating their development.
The ERCB has already adapted the regulatory framework to deep/basin-centred/tight gas, coal bed methane, and in situ bitumen. The ERCB responded with new regulatory structures—Development Entities for CBM and Deep Basin gas; control wells for CBM; commingling of production streams from coal-sand sequences—to more effectively manage the development of some of those resources. After only a few years of operational experience, and with industry feedback, we have already improved the efficacy of some of these approaches and continues this effort as an ongoing practice.
Moving to the next level, however, requires some substantively different approaches. The ERCB's Unconventional Gas Regulatory Framework Project is intended to identify new ways of regulating and facilitating such resource development. It is being done with the consultative input of knowledgable stakeholders. We have already determined the major regulatory risks, and are focusing on developing ways to mitigate them with the appropriate level of necessary regulation or other, non-regulatory means.
Multicomponent Seismic Monitoring of CO2-Enhanced Oil Recovery
Authors: Benson R. D. 
Published: February 2011

Abstract
Time-lapse (4-D) seismic data is often able to detect changes related to the injection of CO2. However, to quantify these changes is problematic. Understanding the CO2 injection process is critical to relating the seismic response to changes within the reservoir. In most CO2 injection projects, a pure liquid CO2 is initially injected into an oil reservoir, combining with the oil, resulting in the oil swelling and becoming more mobile. Reservoir changes include variations in fluid saturation, compressibility, phase and density along with changes in reservoir temperature and pressure.
Time-lapse (4-D), multi-component (9-C) seismic data has been acquired, processed and interpreted in three oil fields that have undergone CO2 injection. Vacuum field has been monitored with four seismic surveys during an EOR project in the San Andres formation with CO2 being injected over a 200 meter zone. Weyburn field has been monitored with three seismic surveys during an EOR project in the fractured Midale member of the Mission Canyon Formation with an approximately 20 meter thick zone. West Pearl Queen field has been monitored with two seismic surveys during a CO2 sequestration test in a 12 meter thick Queen Formation.
Combining the geologic, geophysical and petroleum engineering data allows an integrated approach to interpreting the time-lapse anomalies associated with CO2 injection. Integrating the multi-component seismic data allows the separation of the fluid changes from the pressure changes, allowing a much more definitive interpretation of the anomalies associated with the CO2 injection process. Multi-component seismology is critical in monitoring CO2 movement in the Vacuum, Weyburn, and West Pearl Queen fields.
Evaluating Old Wells for Conversion to CO2 Injectors: Experience From the Rousse Field
Authors: Miersemann U.. , Loizzo M.. , Lamy P.. 
Published: February 2011

Abstract
The RSE-1 well operated by Total is located within the Rousse field in the southwest of France. The 43 year-old well, a gas producer from a now depleted reservoir has undergone extensive research in order to determine its suitability for CO2 storage. The main objective, in terms of containment, is to avoid that the injected CO2 migrates back to the atmosphere or to potable aquifers. Existing wells are often identified as a potential weak point in the containment system, because cement, casing and elastomers can be degraded by CO2 over time. Since any defects within the cement sheath may accelerate this aging mechanism, the material behind the casing should be fully characterized especially across the caprock.
Cement bond log data was available from the 43 year old RSE-1 well, which only gave a qualitative indication of the casing-cement bond, but did not allow a detailed characterization of the material behind the casing. To gain more detailed information, new cement evaluation logs were acquired over the lower 905 m of a 2000 m thick caprock using a new generation 3D ultrasonic cement imager coupled with an array sonic imager. The use of different, independent measurements revealed good casing-cement bond that could be compared to the original logs from 1967 to confirm no degradation over the production life of the well. However, annulus imaging revealed breakouts and a very eccentered casing (almost touching the borehole wall), both of which led to the presence of mud pockets. Detailed evaluation of these pockets indicated that they are not connected and that zonal isolation over the 836 m cemented section of the caprock is indeed achieved. Modeling of cement imaging data also suggested good cement-formation bond, without any external microannulus presence.
Detailed characterization of the material behind casing, casing eccentralization and intermittent mud pockets provided an improved understanding in terms of well integrity. The results showed that the RSE-1 well nevertheless provides adequate hydraulic isolation for the injection of CO2 and that the cement sheath can therefore be eliminated as a potential weak spot in terms of containment.
CCS and CO2-Storage Possibilities in Hungary
Authors: Kubus P.. 
Published: February 2011

Abstract
MOL (Hungarian Oil and Gas Company) in cooperation with ELGI (Hungarian National Research Institute-) recently have completed a screening study in order to determine the CO2 storage potential of HC fields operated in Hungary. Altogether 180 oil or gas reservoirs were involved into the investigation. Integrated data bases were available for the specialists for determination of potential volumetric of the fields. To accelerate the screening process relating to the deep saline aquifers a new methodology was worked out which based on the compressibility of the formations and the highest applicable overpressure. The details of this solution will be presented in details. Based on the conclusions of this study a group of the potential fields were set up providing an important input to the ongoing feasibility study.
As a second step, a desktop survey of the whole CCS value chain was concluded. The biggest existing emitters were mapped with their yearly and daily CO2 output and with the operating technological solutions. Third element of the investigation was the determination of the possible transportation routs of the captured CO2. This integrated approach seemed to be a solid base to determine the optimal connections between the target storage fields and the emitters. The details of the screening process and the target capacities will be summarized in the paper.
A Consortium (MOL, Matra Power Plant, ELGI) established for preparing a feasibility study of the most possible CCS project possibility in Hungary, details will be found in the paper as well, showing the technical solutions of capture, transport and storage plans with economics issues.
Preliminary economics resulted that a full value chain CCS might be viable only with at least 50% EU subvention (both CAPEX and OPEX side), and relatively high and continuously growing CO2 prices (40EUR/t in 2012 growing up to 55 EUR/t in 2020) are the most critical financial issues for the successful project initialization.
Tengiz Reservoir Uncertainty Characterization and Modeling
Authors: Peake W. T. , Camerlo R. H. , Tankersley T. H. , Zhumagulova A.. 
Published: February 2011

AbstractProbabilistic production forecasting at Tengiz is largely driven by reservoir uncertainty. Reservoir uncertainty is most effectively synthesized and quantified through simulation modeling. Early in the construction of a new Tengiz dynamic model, fundamental reservoir uncertainties were identified and evaluated. This allowed for model ‘building blocks’ to be developed with different characterizations to encompass key uncertainties.Key uncertainties, which can significantly impact future production under primary depletion and sour gas injection, have been described. These include typical uncertainties such as porosity, irreducible water saturation, hydrocarbon fluid properties, oil-water contact levels, rock compressibility, geologic baffles, and relative permeability. Unique uncertainties specific to Tengiz include geometry and density of the natural fractures, and reservoir heterogeneity.Considerable production history and a large reservoir surveillance database provided input for rigorously characterizing and subsequently validating the range of each uncertainty. After ranges were established, appropriate model realizations were created. A wide range of reservoir models were obtained by selecting combinations of high/mid/low realizations for each uncertainty. Using experimental design (ED), reservoir simulations were conducted to test uncertainty ranges against field history. A quantitative history match and statistical analysis were developed to objectively judge the appropriateness of uncertainty values. Uncertainties with the largest overall impact on the history match are: fracture density, platform horizontal permeability, compressibility, and platform heterogeneity.This case study demonstrates how analysis of reservoir uncertainties can be: (1) captured in static and dynamic reservoir models and (2) validated through ED and quantitative history matching. This study employs state-of-the-art technologies to evaluate model uncertainties of a giant carbonate reservoir undergoing both depletion and miscible gas drives. The range of reservoir models subsequently developed will be of great value in creating robust probabilistic reservoir forecasts to optimize field operation and future development.
Design, Operations, and Interpretation of CO2 and Water Injection Test in Low Permeability Saline Aquifer
Authors: Kumar Viren , Garnett Andrew , Kumar Giridhar , James Simon , Trivedi Bhaskar , Salunke Sarita , Rao Narsimha 
Published: February 2011

Abstract
ZeroGen-11 is the first pilot CO2 injection well, air drilled by ZeroGen in the North Denison Trough. Its objective was to evaluate low permeability saline aquifers for suitability to commercial scale CO2 sequestration by investigating the injectivity of super-critical CO2 and brine, reservoir ‘k.h’ (permeability-thickness), reservoir continuity. Key activities were the CO2 and water injection test design, well site operations and the interpretation of the ZeroGen-11 CO2 and water injection fall-off test data.
A series of CO2 injection tests and a single water injection test were carried out in ZeroGen-11. The detail design of the tests and selection of various intervals were based on continuous cored data, rock typing, and low cost appraisal wells. The materials for well tubulars were CO2 resistant (13Cr).
Pilot operation activities commenced in mid 2009 and, being the first open-hole CO2 pilot in saline aquifer with unusually low permeability, they faced significant challenges. Operational data from the Australian wellsite was analyzed real time at the Shell Bangalore Technology Centre "Collaborative Work Environment" by an integrated team of discipline specialists which helped for the optimization of ZeroGen operations. The operational experience gained is valuable for low rate injection tests, at high pressures in an open-hole interval under compressive stress regime where fracture gradients as high as 1.1 psi/ft are possible.
The test results established supercritical injectivity of CO2 in matrix condition for high permeable Catherine Sandstone interval at rate of 150 TPD and in low permeability Aldebaran formation at 2-3 TPD. The well test interpretation gives ‘kh’ in the range of 1 md.ft for Aldebaran and 240md.ft for high permeability Catherine Sandstone. The water injection test provides a reasonable calibration point to determine CO2 injectivity, and is expected to be useful in appraisal campaigns in saline aquifers. It is also noted that the CO2 injection test did not show a two boundary signature in the pressure derivative curve that was clearly observed for the water injection test as the presence of CO2 zone near wellbore mask the effects of a boundary signature.