bluuebunny/crossref_metadata_2025_split huggingface dataset:
Heavy Duty Wireline Fishing Operations in a HP/HT Sour Gas Well – A Case Study
Authors: Purwagautama Gustioro , Idi Yusuf A , Syahriza Ghany R. , Vincent John 
Published: September 2011

Abstract
HP/HT gas wells, especially those in South Sumatra, Indonesia, present many challenges to exploitation operations due to a 408°F bottomhole temperature, a 10,500psi bottom hole pressure at some 11,000ft, and sour gas components of 34% CO2 and 100 –200ppm H2S.
During the final stages of the completion of one such well, after setting the production packer a wireline run was made with .108″ slick line to recover the plug body from the seating nipple at 11.406ft. While pulling out and with the plug at 6000ft. the well became live without warning, blowing the tool string up the hole and, to contain the well, the drilling BOPs were closed shearing the landing joint which in turn closed the sub surface safety valve. Subsequently the well was successfully completed and prepared for wireline fishing operations.
The wireline fishing operation went on for several days using .108″ wire, during which 45 runs were made with the recovery of only approximately 550ft of wire and so it was decided to call in heavy duty wireline fishing (HDWF) expertise to review the situation and make recommendations as to how to proceed. This resulted in a commitment being made to mobilize personnel and equipment from Aberdeen and the Middle East to carry out the required operations. In the meantime a total of 11 further runs were made in the well using coiled tubing which resulted in recovery of the upper part of the tool string and some additional wire. Fishing operations were recommenced using 7/32″ Supa 75 braided cable with two two/man crews providing 24 hour operation and a project leader located at the clients office to provide for direct liaison. After a total of 17 runs over 6 days of continuous operation, the fish was completely recovered and the well made ready for production.
In this paper the authors will review the situation that was faced, the remedial work done to complete the well, the early fishing operations and the subsequent input of HDWF expertise. They will conclude with a detailed account of the successful HDWF operation – an excellent example of how careful planning, experienced personnel, dedicated project management and a collaborative relationship between the client and service company can lead to a successful outcome.
EoS Modeling for Two Major Kuwaiti Oil Reservoirs
Authors: Al-Ajmi Moudi Fahad , Tybjerg Peter , Rasmussen Claus P. , Azeem Jawad 
Published: September 2011

Abstract
Two fluids with extensive routine PVT and miscible gas injection EOR data from two different major Kuwaiti oil fields are presented. Eight component EoS models were developed for the two fluids using the volume corrected Soave-Redlich-Kwong equation of state.
A sensitivity study has been conducted on the routine PVT and EOR data for both fluids using multiple linear regressions. The critical temperatures and critical pressures were found to be the most sensitive parameters when modeling routine PVT data, while the EOR data was found to be more sensitive towards changes in acentric factors and binary interaction parameters.
Both routine PVT and EOR data was matched very well with the developed EoS models. With an accurate match of the critical points in the Swelling Test experiments and the near-critical compositions in the Equilibrium Contact and Multiple Contact experiments, the MMPs of the two reservoir fluids were matched very well predictively without further parameter adjustments.
Advanced Mud Logging Aids (AML) Formation Evaluation and Drilling, and Yields Precise Hydrocarbon Fluid Composition
Authors: Loermans Ton , Bradford Charles , Kimour Farouk , Karoum Reda , Meridji Yacine , Kasprzykowski Pawel , Bondabou Karim , Marsala Alberto 
Published: September 2011

Abstract
While traditional mudlogging techniques provide largely qualitative data, the prime objective of Advanced Mud Logging (AML) is to provide quantitative real time measurements in aid of a complete formation evaluation. To achieve this, wellsite mudlogging technologies have been enhanced, and various techniques which historically were limited to laboratories, have been adapted for well site usage. AML well site techniques thus include: (1) high frequency, improved accuracy monitoring of drilling parameters; (2) enhanced cuttings image acquisition and processing; (3) direct measurements on cuttings, including graindensity, spectral GR, NMR, XRD, XRF; and (4) sophisticated mud gas analysis capabilities.
We describe the main system components developed and present some results of the first pilot tests done in Saudi Arabia with AML techniques and a dedicated AML unit. Examples in the four areas mentioned above illustrate and confirm the potential of AML. On one special technology test well, different systems, from two different companies, were run in parallel to establish the merits and possible limitations of especially the hydrocarbon analysis systems.
One of the most striking examples of the quality of AML is a perfect match between the hydrocarbon fluid composition determined from mud gas returns, and those subsequently obtained from PVT measurements on wireline fluid samples. To achieve this, AML technology developers in the industry advanced across the whole process chain affecting such quantification. First and foremost, improving sample extraction and handling, combined with enhanced calibration procedures, to convert from in situ to surface conditions. Second, in addition to sampling both the return mud flow and the inflow, a more precise tracking of flowrates and system volumes was made possible with modern operating systems. Third, adding a mass spectrometer to the gas chromatograph, improved the final measurement potential.
Full Barrel Analysis: A Simulation Model Interrogation Tool to Assess Sweep Efficiencies and Identify Targets for Improved Oil Recovery
Authors: Beckman M. S. , Dickson J. L. , Harris C. R. , Frankel D. S. 
Published: September 2011

Abstract
A reservoir simulation post-processing tool, the Full Barrel Analysis, has been developed to assess sweep effectiveness and identify targets for improved oil recovery. The tool also quickly determines the potential for increased recovery via enhanced oil recovery methods or improved reservoir management. To perform these functions, the tool extracts information from simulation results and performs novel calculations using SAS®*. The calculations include sub-dividing the oil-in-place into eight categories, which are called ‘sections’ of the barrel, using a combination of cell binning and oil designation rules. The oil in the reservoir is then represented as a composite ‘barrel’, whose composition is represented by these eight sections. These sections used to describe this representative barrel are aligned with potential recovery methods, providing a fast and simple technique to screen reservoirs for recovery methods. The tool reports the volume of each section present in the composite barrel in a succinct format that can be easily interpreted by reservoir engineers and geoscientists. The binning and designation rules used to create the barrel sections allow the user to determine which areas of the field are under gas or water flood, the total immobile oil, the total non-economic oil and areas with improved reservoir management opportunities. In addition, the Full Barrel Analysis provides maps and 3-D data that are valuable tools to analyze the reservoir model for sweep performance, in-fill drilling opportunities, and QA/QC issues. The tool output is also useful for comparing development or geologic scenarios, giving insight into the impact on sweep effectiveness and future recovery potential via improved or enhanced oil recovery methods.
Optimization of Conventional Acid Jobs and the Historical Trend Leading to Multistage Acid Fracturing Stimulation to Increase Gas-Condensate Productivity in Carbonate Reservoirs in Saudi Arabia
Authors: Franco C. A. , Solares J. R. , Asiri K. A. , Al-Shammari N. S. , Alabbad E. A. , Gomez F. A. 
Published: September 2011

Abstract
The majority of the gas-condensate reserves, currently being developed from fields located in southern Saudi Arabia, come from tight carbonate reservoirs, which require acid stimulation to achieve gas rate targets and field development objectives.
Most of the gas producers drilled at the beginning of the gas development program were vertical completions, the majority of which were acid fractured and achieved excellent post-stimulation results. As the development scope expanded to areas with tighter reservoir characteristics, the majority of new wells were drilled as open hole single or dual lateral completions to achieve maximum reservoir contact (MRC). A significant number of these wells did not require acid stimulation, but many others did, either to increase productivity in underperforming wells, or to remove drilling induced formation damage. The most recent approach in the evolutionary process is to drill single lateral open hole horizontal producers and fit them with a completion designed for multistage fracturing treatments.
This recent approach has allowed Saudi Aramco to effectively stimulate the entire horizontal section, optimize treatment designs, and achieve excellent post-stimulation results and high gas rates from wells drilled in even tighter reservoirs. This paper describes the historical trend leading to the selection and implementation of multistage fracturing technology as a fit-for-purpose technology to maximize productivity in long horizontal gas producers, and shares post-stimulation results achieved in typical wells drilled and completed throughout the different development phases.
Robust Multi-Phase Flow Measurement Using Magnetic Resonance Technology
Authors: Appel M. , Freeman J. J. , Pusiol D. 
Published: September 2011

Abstract
A compact 3-phase flow meter based on Magnetic Resonance technology has been developed to the prototype stage, and tested in a commercial flow loop.
No single well head meter currently available on the market simultaneously satisfies the customer’s need for accuracy across a broad range of produced volumes and hydrocarbon properties, operational robustness, with low cost hurdle. Consequently, a large number of installations are either insufficiently metered or rely on accurate, yet costly and operationally cumbersome test separators. Insufficient metering may result in suboptimal reservoir management and uncertainty in allocation of co-mingled production.
This development targets provision of highly accurate, real-time quantification of flow rates for oil, water, and gas in multiphase flow. Magnetic resonance is intrinsically sensitive to flow; however, current applications to flow measurement are limited to very low flow rates that are inapplicable to oil-field applications. This meter employs a new principle that enables robust 3-phase flow metering with a broader operating envelope than existing flow meters, has no sensors in the flow stream, no radioactive source, yet could potentially be produced at sufficiently low cost to promote increasing numbers of well head installations. Results obtained at a commercial flow loop confirm a broad operating envelope, accurate 3-phase flow characterization, as well as direct measurement of phase slip.
This paper describes the technical design of the flow meter and presents measurements of individual phase instantaneous velocity and hold up, for all phases under full 3-phase flow conditions acquired in a commercial flow loop. The data includes a range of fluid properties and flow conditions.
Fluid Characterization, A Case Study of a Field with Compositional Gradient
Authors: Kalehbasti Mehdi Alipour , Paroodbari Javad Rostami , Ravari Reza Rostami , Amani Mahmood 
Published: September 2011

Abstract
The phenomenon of variation of fluid properties with depth has been observed in reservoirs with large thickness or high dip angle where primarily the gravitational forces along with the thermal effect play an important role on the overall composition of the system. Compositional grading is more evident in high shrinkage oils, volatile oils, rich gas condensates as well as the black oils. Compositional grading is a key issue in dynamic modeling of the reservoir and must be given enough care during both estimation of the stock-tank initially in place and reservoir performance.
This paper presents an engineering evaluation of fluid characterization of a heavy, viscous oil from an Iranian oil reservoir which is considered for a gas injection project. After screening of all available PVT data, the validated data were input into the PVT package and reproduced all existing experiments with only one EOS. Since there was no firm evidence of different equilibrium regions inside the reservoir, it was decided to have one EOS for the whole reservoir with varying mole fraction with increasing depth.
Viscosity is the main property to be predicted with EOS in this task. Mole fractions of C7+ are critical in this case and need special attention. For regressing experimental viscosity, two regions were defined. The results show that the suggested EOS will lead to a reasonable match of all experimental data and when was used in the reservoir simulation in the next phase of the project, the initial oil in place was close to that obtained based on previous black oil model.
World's First Hybrid Inflow Control Completion in India's Largest Onshore Oil Field
Authors: McKenzie Tim , Wenk Andrew , Khan Parvez , Gavioli Paolo , Andrew Colin 
Published: September 2011

Abstract
The Mangala oil field, onshore Rajasthan, India, is the country’s largest onshore oil producer. The field holds large reserves of high wax viscous crude which have a number of significant production challenges, one of which is an unfavourable oil/water mobility ratio.
The FM3 and FM4 sand units in the Mangala reservoir are being developed with horizontal wells and the well design required a completion to manage sand production and the adverse oil to water mobility ratio with a preference for minimal well intervention. These reservoir units are composed of thick high-permeability sandstones. It was recognised that field recovery and production rates would be optimised by the application of the most suitable technologies available in inflow control management.
This paper describes the successful implementation of the world’s first hybrid inflow control completion for a high wax viscous crude reservoir, including: the hybrid inflow control device selection, completion design and installation, and post-production logs which confirm the performance of this world’s first completion system.
Case History of the First Global Installation of a Gravel Pack System that Allows Continuous Pay Zone Chemical Treatment Pumping Without Interrupting Production
Authors: Surveyor Nilufer , Amaral Anderson , Pinto Marcela 
Published: September 2011

Abstract
Offshore wells, especially deepwater completions, are usually completed with semisubmersible rigs. These use subsea trees, and workovers require moving a costly rig to the location. Solving problems remotely—with an interventionless method—provides huge savings and fewer risks.
This paper focuses on the first global installation of a gravel pack system that allowed continuous pay zone chemical treatment pumping without interrupting production. For wells with issues such as barium and calcium sulfates causing obstruction at the sand control screen base pipe holes, this system allowed pumping of scale inhibitors (or any other chemical treatment) to the end of the horizontal well (toe) or to other parts of open- or cased-hole sections without needing to stop production.
For this first installation, the system incorporated zonal isolation with feedthrough capabilities using reactive element packer and multiple injection nipples technology, taking advantage of a long shale segment to divide the well in two parts. In general, the number of injection nodes with the same pumping line could vary from well to well. However, at this deepwater installation offshore Brazil, the system was designed to allow continuous pumping of chemicals through only one small-diameter down into a horizontal open hole, to inside the sand control screens at two separate sections of the well, one at the toe and another above the reactive element packer.
The system allowed for screen assembly installation and gravel pack pumping in one trip. A reconnect anchor seal assembly was designed and used to deliver a continuality of the flowline conduit from the gravel pack assembly to the upper string assembly. It also incorporated a cost-effective, high-flow liner system for the conduit/injection mandrel protection and a special feedthrough quick connector to simplify certain steps in the assembly. This allowed for torque and traction transmission in open-hole deployment. This paper will describe the implementation and installation of this new system.
Effect of Emulsifier Concentration and Acid Volume Fraction on the Elastic Properties of Emulsified Acids
Authors: Sayed M. A. , Nasr-El-Din H. A. 
Published: September 2011

Abstract
Acid in diesel emulsified acids have been used in the oilfield for many years. Unlike other acid systems, such as gelled and viscoelastic surfactant-based (VES) acids, where the mobility of hydrogen ion controls the overall rate of the reaction, emulsified acid/rock reaction involves the transport of acid droplets in the diesel phase to the rock surface. Upon contact with rock surface, acid droplets breaks and then the actual reaction on the surface occurs. The emulsified acid has several advantages including the minimum number of acid additives and low corrosion rate. The most important properties of emulsified acid are the viscosity, stability and reactivity. These properties are greatly affected by acid droplet size. Based on our knowledge, the effect of the droplet size on the elastic properties of emulsified acid was not studied before.
The main objective of this paper is to provide a detailed description of the elastic properties of the emulsified acid. In order to perform that, a HPHT rheometer was used. The oscillatory shear measurements were carried out on a series of emulsified acid samples. Different parameters can affect the behavior of the viscoelastic properties of the emulsified acid; such as emulsifier concentration, acid to diesel volume ratio, and acid additives.
The rheological properties depend on the droplet size. At low emulsifier concentration, coarse emulsion, elastic properties were dominant only at high frequency. At high emulsifier concentration, fine emulsions, viscous properties were dominant. Acid additives that affect the droplet size will affect the rheological properties of emulsified acid.
Poseidon Gas Handling Technology: A Case Study of Three ESP Wells in the Congo
Authors: Camilleri L. , Brunet L. , Segui E. 
Published: September 2011

Abstract
In the Republic of Congo, the reservoir pressures in the Likalala and Kombi fields have decreased since production start-up and have dropped below the bubblepoint resulting in secondary gas caps. Consequently, the producing gas/oil ratio (GOR) and gas void fractions (GVFs) of the wells have increased. These fields are produced using electrical submersible pumps (ESPs); however, the drawdown has been limited by traditional ESP gas handling technology, which typically cannot handle GVFs higher than 40%. Total E&P Congo installed three ESPs with advanced helicoaxial pump technology in these two reservoirs. After nearly 2 years of operations on wells Likalala 106 and Kombi 102, production has stabilized and increased as a result of eliminating shutdowns and increasing drawdown. On the third well, Likalala 112, helicoaxial technology ensured that production targets were achieved despite unexpected high GOR and GVFs. This paper reviews these applications, focusing on the ESP and well outflow simulations, which demonstrate that the higher GVF handling capability of the pumps provides the technology needed to increase drawdowns. The paper includes analysis and review of well performance, from inflow through to facilities. It also reviews the in-situ GVF performance of the gas handling device with GVFs measurements as high as 80%. A head correction correlation is also matched to the field results providing users with a method for modeling future ESP applications with high GVF. Finally the downhole gas separator efficiency is reviewed and suggestions made on how future completions can achieve higher separation efficiencies. The results are used to provide a benchmark and design guidelines for future high GOR-ESP applications.
Use of Improved Gridding Technique in Coupled Geomechanics and Compositional Reservoir Flow Simulation
Authors: Shrivastava Vijay , Tran David , Nghiem Long , Kohse Bruce 
Published: September 2011

Abstract
Coupled reservoir flow and geomechanics simulations are important in many compositional fluid flow processes like water-alternating-miscible gas injection and CO2 storage. The intention in these models is to understand the effect of stress and deformation consequent to changes in reservoir flow and fluid phase behavior. Safe CO2 storage in deep saline aquifers calls for evaluation of cap-rock and seal integrity via stress responses so that undesired leakage through the seals could be avoided. In the geomechanics calculations unknowns at a large number of finite element nodes need to be solved at each coupling step, which can lead to overwhelmingly large computation time for the coupled simulations.
Recently an improved gridding technique was applied to model coupled geomechanics and reservoir flow in a thermal simulator. In this technique, a dual grid system consisting of separate grids for the reservoir flow and the geomechanics calculations is used. The exchange of information of the variables between reservoir and geomechanics simulators was accomplished in an iteratively coupled fashion. This method showed significant reduction in CPU time compared to single grid coupled simulation.
This paper presents an extension of the above method wherein the geomechanics model is coupled with an equation-of-state compositional simulator in place of a thermal simulator. Use of the dual grid system is demonstrated through simulation models for two compositional processes. Comparison between a dual grid system and a single grid system is presented. The results show that there is substantial saving in computation time and memory requirement without significant loss in the quality of flow or geomechanical results.
The dual grid system presented in the paper can be used to model compositional processes in stress-sensitive reservoirs to yield satisfactory results in considerably less time than would be possible through a conventional single grid system for coupled flow and deformation simulation.