bluuebunny/crossref_metadata_2025_split huggingface dataset:
On the Right Road to High Efficiency and High Speed Recovery: The Experience of Development the Biggest Reservoir in Huizhou Field in South China Sea
Authors: Li Li , Zhang Wei , Qin Feng , Dai Zong , Dai Ling , Shui Min 
Published: September 2011

Abstract
This paper introduced the special development strategy and new technologies used to reach ‘high efficient, high speed’ recovery for offshore H filed, which located at 16/08 block of H fields group in the Pearl River Mouth Basin. As the biggest single lithology reservoir in South China Sea, K22 consisted 80% of the field OOIP. Great challenge was faced when the reservoir was discoverd at the year 1991, for the OOIP of the reservoir thought to be marginal and water depth of this field is more than 110m. Most of reservoir in the Pearl River Mouth Basin belongs to the low-relief anticline structure, while K22 is the first lithology reservoir found in South China Sea. Water flooding was thought to be the first choice for complicated heterogeneous and insufficient water drive energy formation. However, by optimizing well placement and installing ESP, a less but high-yield wells pattern was eventually applied.
After 15 years’ development, the OOIP of K22 is three times larger than original ODP. Current well performance and simulation study indicated the ultimate recovery would reach to 71.5%. The annual recovery factor was more than 10% at its peak year, corresponding to 55000 barrels per day with only 11 producers. The experience of successful development of K22 reservoir is a good story of ‘high efficient, high speed’ development strategy of offshore oil field. On one hand, the anti-rhythm reservoir characterized by good permeability and sufficient natural water energy guaranteed a high recovery factor; on the other hand, the integration of seismic data, single reservoir producing strategy, reservoir management and pay zone protection also play a great role in the process of oil field development.
In OOIP scale, speed of recovery and depletion rate, K22 are second to none among all fields in South China Sea, which has a significant reference value for the development of offshore fields. The technologies proved to be successful in K22, including seismic data frequency extension, the cost-effective streamline simulation and under-balanced perforation have been widely used in the industry.
Hole Cleaning Optimization in Horizontal Wells, a New Method to Compensate Negative Hole Inclination Effects
Authors: Malekzadeh N.. , Mohammadsalehi M.. 
Published: September 2011

AbstractWith increasing measured depths and horizontal displacements in extended-reach (ERD) wells, good hole cleaning and cuttings removal remains a major challenge. Poor hole cleaning may result in lost circulation, hinder the casing or liner to be run into its selected position, excessive over pull on trips, high rotary torque, excessive equivalent circulation density, formation break down, slow rate of penetration, excessive bit wearing and pipe sticking. There are methods and models have been introduced to find the minimum flow rate required to remove the cuttings from the well. Larsen's model that can be used to find this flow rate from 55 to 90 degrees of hole inclination. Another one is Moore's correlation that is used to find the slip velocity of the cuttings in vertical wells.This paper represents a new approach to achieve both optimized hole cleaning and flow rate, as a result of precise manipulations and redesigning of drilling mud rheological parameters, which have been elaborately explained in this paper. Calculations performed by computerized iterations via simulation software, which is developed based on theoretical concepts. Furthermore, Comparisons between calculated data and measured field data have been made. This method is valuable for prediction and calculation of the optimum flow rate for cuttings removal for all range of inclination, namely from 0 to 90 degrees and for providing guidance in further evaluations of this problem as well.Data form a horizontal well YS5 which is drilled in Yort-e-Sha field in Iran is used to demonstrate the application of this method. As the significant outcomes, When the results of optimization applied, good hole cleaning condition achieved and negative effects of excessive flow rate such as drilling mud loss and drag were minimized.
Analyzing Dynamic Reservoir Behavior and Connectivity by Means of Formation Pressure While Drilling Technology
Authors: Salim D.. , Freitas E.. , Oliveira J.. , Lozada O.. , Canas J.. 
Published: September 2011

Abstract
An extensive drilling campaign was done for the purpose of reservoir appraisal of an offshore Brazilian field that included complex deviated pilot wells. One of the objectives of this campaign was to provide detailed reservoir pressure information to determine fundamental reservoir properties. In order to optimize the data collection, it was necessary to acquire pressure measurements and also to transmit real time to validate test responses. Due to the complexity of well trajectories, the solution for executing pressure tests consisted of using Formation Pressure While Drilling technology.
The operation was carried out in five pilot wells providing critical results. The first result was the detection of non-linear reservoir depletions. Pressure tests also identified change of fluid phase in a black oil reservoir containing a gas cap. By comparing the fluid phase and gradient from early exploration wells, it was evident that the free gas was not originally present. This multiphase behavior reinforces the second result: confirmation of the dynamic process that reservoir fluids are undergoing. Moreover, different degrees of pressure depletions were observed in locations up to 1.5 km distant from producer well within same connected reservoir proving third outcome: the long lateral connectivity of reservoir sands. Another important outcome is that the actual bubble pressure is higher in magnitude and the current pressure depletion had fallen below it. The final outstanding result was the potential increase of oil reserves where pressure values identified unexpected sand channels with no drainage or very small depletions. The results of this pressure measurements analysis reinforced the need to optimize the potential capacity of oil recovery through acceleration of drilling injection wells for pressure maintenance.
Implementation of Customized Algorithms Extends Downhole Flowmeter Applications in Two-Phase Oil-Gas Flow: A Subsea North Sea Case Study
Authors: Kiryushkina T.. , Sikandar A.. , Figueroa M.. , Vasper A.. , Balster E.. , Eck J.. 
Published: September 2011

Abstract
The Chestnut field is located in Block 22/2a in the central North Sea. The field, with water depths to 120 m, is approximately 180 km east of Aberdeen, Scotland. Chestnut was first commercially produced in September 2008 by Centrica Energy (formerly Venture Petroleum) using two subsea wells (a horizontal oil producer and a water injection well) tied into a floating production, storage, and offloading (FPSO) vessel. Water injection was required almost immediately because the oil was saturated. A second oil producing well was spudded in September 2008, targeting the South Chestnut field. This well, 22/2a-16Y, was tied into the same flowline and riser as the existing oil producer.
A venturi-type downhole flowmeter was installed in well 22/2a-16Y to obtain continuous pressure, temperature, and flow rate measurements. The production from the other well could then be calculated by subtracting the venturi flowmeter measurements from the total rate measurements made at the FPSO.
Venturi-type downhole flowmeters are, strictly speaking, only applicable in liquid environments because the Bernoulli principle is valid only for single-phase flow and is tenable only in low-slip liquid-liquid flow regimes, such as in the concurrent flow of oil and water at high velocities. Because the Chestnut oil is saturated, it was known that free gas would be seen at the intake of the venturi because the flowing pressure would, by definition, be below the bubblepoint.
To address the challenges caused by two-phase flow through the flowmeter, a workflow was developed that would first assess the quantity and affect of the free gas in the venturi device. The workflow was then developed to increase the accuracy of the flowmeter in the two-phase oil-gas flowing conditions. The enhanced flow calculations were then validated by using FPSO test separator data when only the flowmeter-equipped well was producing. The enhanced model improved the accuracy of the liquid-rate predictions across various rates from initial discrepancies of 40% to 190%, to less than 5%, allowing Centrica Energy to achieve its well- and reservoir-monitoring objectives.
The use of venturi-type flowmeters has traditionally been limited to applications in which only liquid is flowing through the meter. This present case study shows that customized workflows can improve the accuracy of the venturi flowmeter measurements in multiphase environments, making these downhole flowmeters a cost effective alternative to true multiphase meters for certain applications.
Application of Hybrid Artificial Lift to Produce Multizone with High GOR, Contrast PI and Contrast Water Cut
Authors: Matondang A. N. , Ibnu A.. , Subiantoro E.. 
Published: September 2011

Abstract
N-5 well is located on XN offshore platform with ESP completion and was produced with very high water cut. The well was completed and perforated in A, B, C and F zones with straddle packer to isolate E zone. One time the water cut was suddenly decreased. The analysis of well completion suspected that there's leaking on Straddle packer covering E zone which the booked recoverable reserves 2 MMSTB was not appraised yet. The previous N-5 production data from Dec-00 to Jan-01 reported that the E zone can't produce continuously due to excessive gas which caused ESP shut down by gas lock problem.
Referring to the DST result of the offset well (N-1 well), found that the E zone have a good oil bearing, and good reservoir properties (Porosity, Permeability, Swi). Evaluation was made to identify any possibility to produce E zone with customized completion design. Combination of gas lift valve, ESP gas separator, VSD and selective completion was made and successfully anticipate gas lock problem on ESP. The gas can be separated from ESP, then release it through gas lift mandrel above the ESP.
In the initial condition after workover job, N-5 well was produced from E zone with very low rate and caused ESP shut down due to low influx. By taking advantage from selective completion we could optimize production through "Switching Method".
Optimization completion design by using combination of gas lift valve, ESP gas separator, VSD, and selective completion resulting continuous production from E zone, reducing 99% water production, increasing oil production of N-5 well, and move reserve status of E zones from 1P to 2P.
Knowledge Transfer and Introduction of a Remote Operations Model Developed over a Decade - From the North Sea to Brazil
Authors: Saeverhagen E.. , Thompson K.. , Dagestad J.. , Tardio M.. , Bersaas K.. , Grøvik L 
Published: September 2011

Abstract
This paper will provide a description of the benefits of the remote operations alternatives developed over a decade in the North Sea. Substantial support from Hydro/Statoil, starting in 1999, with remote data monitoring, re-manning the rig site with remote support, and the transfer of rig-based work tasks to a remote operations centre has changed the way we operate today and will also influence how automation will be integrated in the future.
Reduction in personnel-on-board (POB) and alternative remote operational models implemented resulted in measurable reductions in cost and HS&E exposure. The paper will give a thorough description of how continuous high operational performance and efficiency gains to operations at different levels has been achieved and documented in the North Sea and translated to the Brazil environment.
Other key areas for discussion are: improved performance and reliability, decreased NPT, standardized work processes, 24/7 technical support, real-time drilling optimization, cross-training of personnel, real-time data processing, immediate access to experts.
Current remote operations models will continue to evolve by further integrating several classic service deliveries, like directional drilling, measurement and logging-while-drilling (MWD/LWD), mud logging, drilling fluids, wireline logging and other services and job functions. This integration will occur because automated advisory systems will be available, delivering advice based on a wider range of surface and downhole data as well as historical databases and best practices, replacing individual judgment and assumptions. This will significantly contribute to improved HS&E performance as well as risk mitigation.
Automated systems in close combination with new cross-trained functions in the operations centers and re-manning of rig sites with reduced POB therefore will become the next step in automation of the overall drilling process.
Long Term Positioning Technology for Deepwater Drilling Applications
Authors: Hanton S.. 
Published: September 2011

Abstract
The discovery and progression towards development of increasingly deepwater fields in recent years has been obvious, as has the increase in technology developed to support the technological challenges associated with this.
Developments are becoming faster and more cost efficient, but this puts pressures on schedules with offshore SIMOPs becoming ever more commonplace, and vessel and rig operations more safety critical. Maintaining position is a key part of safe SIMOPs, with the vast majority of vessels now being equipped with DP systems for station keeping. These systems are technological wonders, but are completely dependent on the quality of data being provided to them from the various sensors. Surface positioning today is very much reliant on Global Navigation Satellite Systems (GNSS) of which GPS (Global Positioning System) is the current preeminent example.
Although often perceived as ever reliable, GNSS signals are vulnerable to interference with one major source being from charged particles in the earth's atmosphere. During periods of increased sunspot activity a charged stream of solar particles (the solar wind) interacting with the earth's ionosphere can create geomagnetic ‘storms’ which can affect all radio signals (including those used by GNSS) up to and including complete loss of signal. These effects are often referred to as scintillation, which is a rapid fluctuation in signal phase and amplitude.
Acoustic positioning solutions are therefore a critical component of the DP system, but historically seen as a poor relation to satellite positioning
The challenges associated with acoustic positioning systems, from technical and commercial aspects, along with a potential solution, will be explained and discussed over the next few pages.
The Quest for Drilling Optimization Improvement by Using Business Intelligence Methods
Authors: Thomson Ian J. , Vulgamore Dustin J. 
Published: September 2011

Abstract
In today's market, service and oil companies must invest heavily in research and development of new technologies to succeed in the increasingly demanding drilling environment. They must also implement the most appropriate drilling techniques and best practices to overcome the drilling and geological challenges to reach their targets more efficiently.
In an offshore drilling operation, understanding the main drilling challenges for each individual well is not always an easy task. Consequently, identifying opportunities for improvement is not always straightforward, and requires thorough drilling data gathering and analysis to provide more applicable solutions.
The use of knowledge management technology and processes to gather and analyze data to gain a better understanding of the main challenges in a particular application, combined with the design of solutions based on the findings, is commonly referred to as business intelligence.
This paper will present how a service company uses business intelligence methods to acquire relevant drilling data and import it into knowledge management systems prior to performing data analysis to benchmark performance and identify drilling hazards and opportunities for improvement.
Key drilling data obtained from select Gulf of Mexico wells from 2007 to 2009 were studied to determine, by statistical analysis, the most common sources of nonproductive time, which is the main reason for pulling out of the hole and the most common reason for out-of-specification runs. Understanding those factors is crucial for implementing appropriate corrective actions and developing new technology, along with planning and executing best drilling practices.
A Multistage Approach to IOR/EOR Screening and Potential Evaluation
Authors: Surguchev Leonid M. , Reich Eva-Maria , Berenblyum Roman , Shchipanov Anton 
Published: September 2011

Abstract
This paper presents an evaluation study and some latest advances in a multi-stage approach to selection of EOR strategies. The essence of a multi-stage approach is in combination of first-order screening based on ranges for critical oil parameters, statistical data from the world wide database, analytical modelling of IOR/EOR process and economic / risk evaluation.
Screening and analytical methods are often used for fast preliminary evaluations of various EOR scenarios. Advantages of this approach are its speed, relatively small amount of data necessary to estimate the recovery of a particular EOR technique and a dispersion free analytical solution. Simplified representation of the reservoir used in analytical simulation aids in understanding dominating effects and forces and may be used to verify numerical results. The approach is viable and practical when a large number of reservoirs are to be screened for EOR applicability or when a decision over a new asset with limited field data is to be made.
This paper presents new database and improvements in cluster analysis used for estimation of recovery factor. We present a new flexible methodology allowing adding or removing database entries followed up by re-clusterisation and finally cluster-analysis based evaluation of the recovery factor.
A new improved methodology to evaluate performance of the WAG injection is discussed. A three phase compositional path (based on realistic relative permeabilities and rock properties) for each simulation layer is used to determine residual oil saturation to WAG. This value is later on used in analytical evaluation of WAG performance.
Economical evaluation would be integrated into the tool allowing performing economical analysis based on the analytical production profiles calculated within the tool or external data. The economic evaluation may be carried out in "simplified" or "advanced" mode. Advanced mode allows more detalization in specifying costs, while simplified model allows for faster economical evaluation when in-depth economical evaluation is not possible.
Finally a case study of an actual reservoir is presented illustrating how the "EOR compass" could be used in real life situations. The field case presented illustrates screening a new asset as a gas injection candidate. The field in study was taken through a three stage technical evaluation looking at applicability of key development strategies, comparing to the available field cases in the world and finally performing a sensitivity study using an analytical layered model.
Reduction of Perforating Gunshock Loads
Authors: Baumann C.. , Bustillos E.. , Guerra J.. , William A.. , Williams H.. 
Published: September 2011

Abstract
Thousands of well perforation jobs are executed successfully around the world each month; however, certain perforation jobs require special design considerations to minimize the risk of equipment damage due to perforating gunshock loads, such as bent tubing and unset packers. Perforating gunshock loads generate pressure waves in the completion fluid and stress waves in structural components. The magnitude, duration, and timing of these waves depend on job parameters that can be adjusted by the design engineer, such as type, length, and loading of guns, number of shock absorbers, distance from sump packer to bottom of guns, and distance from completion packer to top of guns. The sensitivity of peak loads and gunstring movement to key design parameters can be evaluated with a software tool specifically developed to predict well-perforation induced transient fluid-pressure waves and the ensuing structural loads. All relevant aspects of well perforating events are modeled, including gun carrier filling after firing, wellbore pressure waves and associated fluid movement, wellbore pressurization and depressurization by reservoir pressure, and the dynamics of all relevant gunstring components, including shock absorbers, tubing, and guns.
Existing fast-gauge pressure data from a large number of perforation jobs were used in previous jobs to verify that predictions made by using software simulation are sufficiently accurate, both in magnitude and time; thus, the transient pressure loading on well components is sufficiently accurate to predict the structural dynamics response and the associated gunstring loads. In this paper, we present case studies that show how key elements used for gunshock mitigation are simulated, and the sensitivity of peak loads and deformation to gunstring elements, such as shock absorbers, gun types and loading, tubing size and weight, and packer placement.
With this software, we evaluate the dependence or sensitivity of peak loads and gunstring movement to key design parameters, and when necessary, design changes are made to reduce potentially unsafe load conditions. The design verification and optimization methodology described in this paper reduces significantly the risk of nonproductive time and fishing operations. Key technologies described in this paper enabled the successful execution of many deepwater high-pressure (HP) perforation jobs, including Petrobras' Cascade and Chinook, the largest deepwater HP perforation jobs done to date in the Gulf of Mexico.
Expert System for the Optimal Design and Execution of Successful Completion Practices Using Artificial Bayesian Intelligence
Authors: Al-Yami A. S. , Schubert J.. , Beck G.. 
Published: September 2011

AbstractTo the best of the authors' knowledge, there are no standard guidelines to help in the effective design of completion practices. Many completions have been analyzed in this project, resulting in the best practices, as outlined in this paper.The objective of this paper is to propose a set of guidelines for the optimal completion design, by integrating current best practices through a decision-making system based on Artificial Bayesian Intelligence. Best completion practices collected from data, models, and experts' opinions, are integrated into a Bayesian Network BN to simulate likely scenarios of its use, that will honor efficient designs when dictated by varying well objectives, well types, temperatures, pressures, rock and fluid properties.The described decision-making model follows a causal and uncertainty-based approach capable of simulating realistic conditions on the use of completion operations. For instance, the use of water swelling packer dictates the use of organic acids instead of HCl acids. However, rock type and well geometry affect our selection of treatment fluids. Another example is selection of sand control method based on rock properties. The paper also outlines best operational practices in fracturing, sand control, perforation, treatment and completion fluids, multilateral junction level selection and lateral completion. The paper also discusses in details special well completions. Completion experts' opinions were considered in building the model in this paper.The outcome of this paper is a user-friendly tool, where one can easily find the specific subject of interest, and by the click of a button, get the related information you are seeking. Field cases will also be discussed to validate this work.