bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multiphase Progressive Cavity Pumps Operated In Harsh Conditions
Authors: Seince L.. , Caballero D.. , Chacin N.. 
Published: February 2011

Abstract
The multiphase progressing cavity pump, PCM Moineau HR (Hydraulically Regulated Progressive Cavity Pump), is a major improvement in the operating philosophy of the traditional PCP. By design, the volumetric pump is capable of handling solid, liquid and vapor phases. However, solid leads to abrasion and vapor to overheating and reduced life span where liquid is usually the added value in the process. Several papers have been issued at the SPE PCP, showing first the promising characteristics of this new principle on test bench and then the first industrial version in Venezuela. The learning curve associated with the failures has enabled to come up with a new design that resolves the abrasion and the mechanical weakness of the former NPCP (old name for this multiphase pump), keeping the core advantages of the multiphase design, that is balancing pressure and temperature homogeneously all along the pump, to get an optimum performance and a mucher higher runlife.
This paper presents the case story of a HRPCP installed in Venezuela with Equimavenca, running in harsh condition with heavy gassy oil, as well as the improvement performed ever since. It has been running for more than 20 months, producing 1600 to 2300 scf/sbl of gas.
Seismic Attribute Analysis Role in Reservoir Characterization - A Successful Application to a Giant Offshore Carbonate Field Abu Dhabi, UAE
Authors: Zhang Jie , El-Awawdeh Raed , Shevchek Zyg J. , Khouri Naeema A. , Jan Kamran S. , Harris Christopher E. , Reilly Joe M. 
Published: February 2011

Abstract
A recent reprocessing of a large Ocean Bottom Cable (OBC) seismic data set of a Giant Offshore Carbonate Oilfield in U.A.E. resulted in significant seismic imaging, signal/noise ratio, and detectability improvements of faults and horizon geometries which included new fault system sets never recognized before. In addition, seismic amplitude fidelity was improved significantly and it has been confirmed by well-to-seismic ties, acoustic impedance inversion, and quantitative attribute analysis. This paper will mainly focus on the results of the acoustic impedance inversion and porosity prediction by seismic attribute analysis and applications to field development.
Hundreds of regular wire-line and/or cross-dipole sonic logs were acquired and dozens of ultrasonic measurements from core samples were performed across the field. Data was conditioned and analyzed to understand the porosity versus impedance and other rock physics trends. A relatively narrow porosity versus impedance trend was observed in the data set, which laid the foundation for our subsequent analysis. Acoustic impedance inversion were performed by 1) well-to-seismic tie and wavelet estimation, 2) earth model building based on interpretation and well data, 3) band-limited impedance inversion and total impedance derivation. The inversion results and seismic stacks were loaded into a seismic attribute analysis package where multi attribute analysis was performed and porosity versus impedance and other attribute relationship was established. The porosity volume was then generated across the entire field based on the established relationship.
The resulted porosity volume based on the inversion results and other attributes and extracted maps from these volumes for different intervals were validated with well data where high consistency was observed. Since these volumes are layered properties not interface based reflectivity data like stack seismic, they can be directly correlated to geologic layers such as lithological unit etc. therefore they make the integration of geological and engineering data much easier. The volumes show higher resolution than regular stack seismic data and examples will be shown how this data has been used for thinner reservoir mapping, well planning, and input for geological models.
Monitoring PCPs in 500F Steam Flood Applications
Authors: Cudmore Julian , Al-Araimi Khalid 
Published: February 2011

Abstract
PCP technology has progressed to enable their application in high temperature environments. Typically PCP elastomers limited the temperature range for operation to approximately 150C, but the recent introduction of metal to metal pumps has removed this ceiling. Operation above 150C also provided a challenge for the downhole gauges used to monitor the pump and well performance as downhole gauge electronics designed for PCP monitoring were also typically limited to around 150C operation.
This paper discusses the introduction of permanent high temperature gauges designed for application in steam flood wells lifted by PCP. The field trials revealed various challenges and hurdles which were overcome to design a monitoring system suitable for an extremely challenging operational environment. The paper details the operational environment, challenges encountered and successful deployment of gauges monitoring wells produced by PCP’s in temperatures above 400F.
GOM Deepwater Field Development Challenges at Green Canyon 468 Pony
Authors: Weatherl Michael H. 
Published: February 2011

AbstractGulf of Mexico (GOM) deep water has proven in recent years to be one of the most prolific oil production provinces in the world. The bulk of the new reserves and production to date in this area flow from subsalt, Miocene reservoirs at fields including Shenzi, Tahiti, Thunderhorse, and others (1).In the summer of 2005 Hess Corporation entered this arena and drilled the Green Canyon 468 ‘Pony’ discovery well. Information collected during subsequent appraisal drilling revealed significant insight into subsalt oil reservoirs which exist at depths between 28,000’ and 31,000’ TVD in this area. Geologic, reservoir engineering, facilities, and well construction studies have since resulted in a degree of clarity around the technical and economic viability of field development going forward.Of critical importance is addressing structural uncertainty below salt across Blocks 468 and 469. To reduce this uncertainty further appraisal drilling was approved late in 2009 on the eastern flank of the field. In addition to further structural and reservoir definition, Pony 3 objectives included a more robust casing design with deeper settings and larger diameter hole sections below salt to further confirm feasibility of future production wells. The 2010 program also included the utilization of a six generation dynamically positioned drill ship Stena Forth which provided a valuable advantage versus the single activity, moored semi-submersible utilized on earlier wells.Challenges inherent to ultra-deep wells in deepwater have been well documented in recent years (2, 3, 4, 5, 6). Hence, this paper will focus primarily on Pony well construction and deepwater field development planning. A number of key design issues will be highlighted including pore pressure/fracture gradient regression, casing design, bitumen (tar) mitigation, and salt creep mitigation. Incorporation of lessons learned and best practices from the substantial history of other deepwater operators has been a priority throughout this effort. Engineering and design in partnership with other operators is recognized as a critical element to ensure success in this challenging environment.
Casing Wear Prediction and Management in Deepwater Wells
Authors: Calhoun Bill , Sheldon Langdon , Wu Jiang , Hogan Phillip , Rutledge Kory 
Published: February 2011

Abstract
Deepwater Gulf of Mexico wells are generally deep and they may incorporate casing designs that provide only a single-casing barrier between the wellbore and the formation. These aspects present unique issues and risks in regard to casing wear. The extreme depths (&gt;30,000 ft) of many wells in the Gulf of Mexico create the potential for high side loads imparted by the drillstring to the casing, even with low doglegs (1.0°/100 ft or less) in the upper part of the well. This, combined with potentially high rotating hours, particularly on exploration wells with sidetracks, creates the potential for casing wear that exceeds allowable limits.
In order to proactively manage and mitigate casing wear during drilling operations, Chevron has developed a Casing Wear Monitoring standard operating practice (SOP). Deployment and application of this SOP has proven effective. Application of this SOP indicates that casing wear can be predicted, managed, and/or mitigated with proper planning and execution.
This paper illustrates a casing wear event on a Chevron well and provides an overview of the Chevron Deepwater Casing Wear Monitoring SOP. Additionally, the paper highlights some casing wear processes, well control issues, and environmental risks that are unique to deepwater wells. Application of the casing wear prediction and monitoring procedures outlined in this paper help to ensure that the integrity of the casing is maintained during drilling operations, thereby reducing the risk of a health, safety and environment event or loss of the well due to excessive casing wear.
The Development and Application of A Novel Free-damage Fracturing Fluid pH&lt;2
Authors: Zhang Jin , Zhang Yan , Wu Yongfu , He Xiuqing , Zhang Xinzhu 
Published: February 2011

Abstract
At present, water-based fracturing fluid systems are mainly polymer (macromolecule) and visco-elastic surfactant (micromolecule). Because of polymer properties and incomplete gelout, the damage to matrices and conductivity of artificial fractures will be inevitable. The surfactant-based fracturing fluid system is a micro-molecule system not to damage artificial fractures. However, it is difficult to eliminate the damages from rock debris moving and clay swelling in formation. A novel free-damage fracturing fluid system (FDFF), a cationic surfactant derived from a long chain fatty acid, has been developed and applied in Daqing oil field. FDFF can crosslink in a wide range from a strong acid to a weak acid, and its performance inherits the properties of traditional VES. Because its molecules can be crosslinked in acid, the fracturing process is simultaneously an acidizing process. The pollution to the vicinity of well, therefore, is cleaned out. Meanwhile, the damages of particle motion and plastic strain of the formation near cracks are alleviated so that the high permeability zone around artificial cracks is created. The damages induced by a fracturing treatment are completely removed. The rheology, leakoff, capacity of carrying proppant, and conductivity of FDFF together with its case studies are demonstrated in this paper.
Design of CO2 Dehydration and Compression Facilities
Authors: Kumar Satish , Zarzour Othman , King Graeme , Carbon Masdar 
Published: February 2011

Abstract
Abu Dhabi has been importing natural gas for domestic consumption since 2007 and at the same time has been injecting natural gas into producing oilfields for reservoir management and sequestration. An opportunity exists to inject CO2 instead and release valuable supplies of natural gas for other uses while reducing greenhouse gas emissions. CO2 suitable for injection will be available as part of Masdar’s Carbon Capture and Storage (CCS) project which will capture wet CO2 at atmospheric conditions from industrial plants and facilities, dehydrate it, compress it, and transport it by pipeline to producing oilfields for injection.
This paper presents options for dehydrating and compressing CO2 to achieve the optimum result while meeting all technical requirements. Technical and economic aspects of CO2 water content specification are analyzed and discussed along with current international practices. It focuses on challenges faced by the design team in developing water content specifications and selecting dehydration technology and methods for the Masdar CCS project.
Dense phase CO2 exhibits retrograde water condensation behaviour at pressures and temperatures used for pipeline transportation and injection. This means that CO2, unlike natural gas, can carry more water rather than less as pressure increases. Other products such as natural gas do not share this property with CO2 at pipeline operating conditions.
Pipelines in hot countries such as the United Arab Emirates (UAE) operate at higher temperatures than pipelines in North America and Europe and this enables them to carry product containing more water without it condensing. Therefore allowable water content specifications established by the pipeline industry in North America and Europe are unnecessarily restrictive for pipelines in hotter countries.
Retrograde water condensation in dense phase CO2 combined with higher pipeline operating temperatures in the UAE and other hot countries, permits higher allowable water content for pipelines carrying CO2 than is typical in other parts of the world. The specification of higher allowable water content can reduce both capital and operating costs of dehydration equipment leading to improved economics for CCS projects.
New Approach in Seismic Processing of Dual Sensor 3D OBC Data: Case Study from Shallow Marine Offshore Abu Dhabi
Authors: Mahgoub Mohamed , Obaid Khalid , Witte Johan 
Published: February 2011

Abstract
An important role of the geophone component in seismic OBC data is to allow attenuation of the hydrophone receiver ghost by summing geophone to hydrophone data (PZ summation). This ghost shows as a perfect notch in the seismic bandwidth which cannot be removed by filtering or deconvolution.
Early PZ summation has been the standard processing practice. However, as the geophone signal-to-noise ratio is lower than that of the hydrophone, the geophone component contributes less if summed early in the processing flow, especially in the presence of dispersive noise generated by a hard sea bottom, source generated noise, etc. In this paper an alternative workflow is discussed, in which the two components are processed separately until imaging. The workflow has significantly enhanced the contribution of the geophone component.
Post-stack refinement has shown its merits in data quality enhancement, allowing better matching of the two sensors which is essential for subsequent PZ summation. The differences in coupling and impulse response of the two sensors were corrected by deriving a reliable operator to match the common geophone stack to the corresponding hydrophone stack.
The final imaging product of the geophone component has an advantage over the hydrophone as it contains less multiples and wider bandwidth, allowing better structural interpretation. Late PZ summation has resulted in a much improved resolution and interpretability, especially at deeper target levels than the early PZ summation processing flow of the previous processing vintage.
Employing a Systematic Scientific Approach to Ensure Successful Implementation of Underbalanced Drilling Technology—Case Study
Authors: Sharma G. K. , Sharma M. K. , Lama T. , Duttagupta S. , Ganguly B. , Qutob Hani , Boutalbi Said , Villatoro Jaime , Lakshminarayanan Sunil , Kulkarni Nitin 
Published: February 2011

Abstract
Oil India Limited (Oil India) is considering adapting new technologies to ensure that oil and gas strategic resources are optimally explored, developed, and produced during the life cycle of their fields. Underbalanced Drilling (UBD) technology, which can achieve these objectives effectively when applied in conjunction with horizontal drilling techniques, is being considered among various options.
Accordingly, Oil India decided to pioneer the introduction of this new technology in their onshore oilfields by employing a systematic scientific approach to screen the Makum-North Hapjan Oilfield for UBD candidacy. The screening process involves detailed evaluation of reservoir, production, drilling, geology, geophysics, and operational data with risk analysis incorporated into a rigorous expert system aimed at maximizing the value of any UBD operation. The screening process was performed in two phases: a low resolution screening and an in-depth high-resolution analysis.
Phase I objectives were to evaluate and rank Oil India’s reservoirs for UBD in comparison to conventional (overbalanced) drilling techniques, compare candidate reservoirs against global database of UBD analogs and select a candidate for phase II detailed reservoir damage analysis and productivity forecast. Phase II objectives were to identify the formation damage mechanisms that are expected to occur in each of the three reservoirs and determine productivity and economic improvement of underbalanced compared to overbalanced drilling.
This paper describes the expert system methodology used and provides a discussion of the results obtained. Phase II study findings provided Oil India with confirmation that UBD could provide improvement compared to conventional drilling and completion technologies. The scope of the study also included a complete engineering evaluation for drilling and completion of a new horizontal well – underbalanced, including the use of a downhole isolation valve.
The Potential of Advanced "Look Ahead" Sensors in Complex Drilling BHAs
Authors: Sohmer M. , Reich M. 
Published: February 2011

Abstract
State of the art bottom hole assemblies (BHA) are equipped with a variety of directional and formation evaluation sensors. The drilling industry is used to safely navigate through the reservoir without interrupting the drilling process, evaluate the porosity and properties of the surrounding rock, identify the content of the pore space and measure the movability of the fluids in the pores. And these are only some few examples of state of the art technologies.
To date the sensors usually still look into the formation sideways out of the BHA, while the much more interesting view from the BHA into the space ahead of the drill bit is not possible yet. However, latest developments seem to indicate, that true "look ahead sensors" might be made available soon. A very promising approach deals with seismic measurements. Scientists have found practical ways to focus the seismic energy into a dedicated segment of the rock space around the sensor assembly, making a "directional view" into the formation possible. Provided, the seismic energy could be focused into an area ahead of the drill bit, the general concept for a true look ahead sensor would be on hand.
However, before a field proven commercial tool can be integrated into a full blown drilling BHA answers to a variety of open practical questions will have to be given. Where in the BHA will the sensor be positioned? How can the "event horizon" of a BHA, the space which can be reached by the drill bit, be specified?
This paper will develop a vision of the capabilities and limitations of next generation BHAs with integrated advanced "look ahead" sensors.
Validation of Numerical Model for Simulation of Drilling Discharges to Sea
Authors: Rye Henrik , Furuholt Edgar 
Published: February 2011

Abstract
The site survey for the location of the Trolla exploration well in the Norwegian Sea revealed numerous potential locations of cold water corals. These corals are expected to be vulnerable for sedimentation of particles and exposure to chemicals from drill cuttings and drilling fluids. How vulnerable they are for these disturbances is, however, not well known.
Numerical simulations were performed to predict spreading of drill cuttings and drilling fluids, including concentrations in the water column and sedimentation on the seabed. A monitoring program was also conducted, comprising cuttings particle size measurements, current measurements, sediment traps collecting depositing particles, sediment sampling, turbidity measurements and video observations. The monitoring program gave the possibility to compare results from the numerical model with observed deposition of drill cuttings.
The simulation results showed good correspondence with the contents in the sediment traps, supporting the validity of the numerical model.
What Does It Take To Evaluate A Potential CO2 Storage Site? The ZeroGen Example
Authors: James Simon , Garnett Andrew , Kumar Giridhar , Kumar Viren , Rao Narasimha , Trivedi Bhaskar , Gupta Arjit , Salunke Sarita , Sarkar Subhendu , Srinivasan Ashwin , Meen Prem , Doran Seán , Hall Nick , Barlas Peter 
Published: February 2011

Abstract
The effort, timeline and budget required for CO2 storage site characterization is often underestimated. Depending upon geology, volumes and composition of the CO2 stream to be stored, data acquisition, that may involve appraisal wells, injection tests, Special Core Analysis (SCAL), geomechanical and geochemical experiments, the timeline to conduct the site characterization may run into years and the budget required into tens of millions of dollars.
Experience in site characterization, in many different CO2 storage projects, has enabled a "roadmap" to be developed showing key decisions and work activities from initial screening through to the final investment decision. The primary focus of the roadmap is on the work scope of an integrated subsurface team, but it is part of a broader integrated set of activities which include capture, transportation, and storage elements. This roadmap has been used in the characterization of a CO2 Storage Site for ZeroGen in Queensland, Australia.
For each phase of the project, work activities are directed at reducing uncertainties to the point that key project decisions can be taken. The culmination is a final CO2 Storage Site Development Plan. Interdisciplinary risk and uncertainty assessments are key steps along the way which drive appraisal and data collection tactics. As new data is assimilated into the site assessment the work proceeds, in an iterative manner, as the views on Storage Site Capacity, Injectivity and Containment evolve. Throughout the site characterization phases, common threads, like the Monitoring Measurement and Verification strategy, are matured from an initial range of identified approaches and technologies into an Operating Philosophy.
Constant and early attention and priority is given to Heath, Safety, Environmental and Community issues throughout the work activities and milestone reviews. Besides our personal and corporate responsibility to the community and environment, establishing a strong record of safe and responsible operations will be an enabler towards public acceptance, cost effectiveness and schedule reduction for future projects. Early and constant community consultation is a critical issue to ensure public understanding and acceptance of CCS.