bluuebunny/crossref_metadata_2025_split huggingface dataset:
Detailed Laboratory Investigation of Acid Soluble Cements as Solution for Lost Circulation Across the Producing Zones
Authors: Seymour Brian , Santra Ashok 
Published: October 2013

Abstract
Lost circulation or total loss of drilling fluid or cement slurries in the cavernous formation, permeable zones and natural/induced fractured zones during the drilling and/or cementing operation can be an expensive and time-consuming problem. The consequences of lost circulation could be from the possibility of a blowout to the complete loss of well. Typical solutions for lost circulation has been a pill containing in-soluble materials like platelets, fibers or sized particulates. However, such in-soluble or non-removable materials can cause permanent damage to the producing zones by plugging pores due to in-soluble fines migrations. In some cases, plug dislodgment the can cause premature return of the lost-circulation itself.
This paper describes the results from our laboratory development of two different kind of acid soluble cement systems namely (a) traditional Portland cement based system with appropriate amount of CaCO3 and (b) Magnesium-Oxychloride-Cement (MOC). In both these systems, sized CaCO3 has been used to enhance the bridging effect at highly permeable formations. In addition, we have carried out extensive research to optimize the final set cement compressive strength by optimizing particle size distribution of CaCO3 In addition to bridging capabilities, these fluids can be foamed to enhance the capability of preventing severe lost circulations. Quick setting and 100% acid solubility properties of the MOC systems is the key for minimizing the damage of the producing zones from fines plugging and/or deeper invasion. Laboratory results such as thickening time, compressive strength, and rate of acid solubility will be discussed to compare these two systems in terms of their application pros and cons. In addition, other plausible applications for such acid soluble settable systems will be discussed for both oil and gas wells as a temporary plugging materials.
A Holistic Approach to Screening Stage of Shale Gas Resources
Authors: Navarette Mike , Chorn Larry , Maucec Marko 
Published: October 2013

Abstract
Source rock reservoirs (SRRs) are found in conventional oil and gas basins. The exploration for and the evaluation of an SRR depends on the geology, geochemistry, and petrophysical and geomechanical parameters, as well as economic constraints in the targeted area. The SRR exploration methodology is fundamentally different from conventional exploration as SRR objectives require a program that includes a data-acquisition focused effort in the early stages of exploration and appraisal. This paper highlights a holistic approach to shale gas development that has been developed in detail, encompassing more than 25 years of service company experience in US shale plays. Unconventional SRRs impose significant engineering constraints because reserves are spread out across large compartmentalized, stacked, or layered reservoirs, which are highly heterogeneous (faulted and fractured) and confine wide ranges of mineralogy. The objective of this work is to provide a better understanding of SRR quality and deliverability to assist with maximizing well productivity, improving hydraulic fracturing stimulation, and optimizing drilling and completion efficiency. This paper identifies critical paths and key technical elements or tasks associated with SRR basin screening and evaluation. Commercially successful analogs are used to evaluate and benchmark potential hydrocarbon reserves. A methodical approach that addresses the following key tasks is presented: Determine critical SRR attributes.Map selected attributes in the SRR model.High-grade the regions in the basin with the best potential.
This work provides a proven road map for the evaluation and development of SRRs. Critical paths with the associated key technical elements address and provide a project scope of challenges, which enable a holistic solution to successful unconventional SRR development.
Logging Sub-Hydrostatic, Single-Completion Wells with Concentric Coiled Tubing Technology
Authors: Ababou M.. , Shote A.. , Sturgon T.. 
Published: October 2013

Abstract
Historically, logging sub-hydrostatic wells to determine water entry points was restricted to a limited number of wells of a particular construction. These wells had to be dual-completion wells or 9 5/8-in. cased wells, able to accommodate dual-string completions. One string would be used for running the logging tool via coiled tubing or wireline, and the other would be used for artificial lift and produce the well while logging.
Single-completion wells were a challenge for production logging runs because two strings of tubing and dual wellhead would be required, necessitating workover rig operations. However, for smaller cased holes such as 7- or 4 ½-in. casings, running a dual completion string is typically too complex or impossible. When operators had to determine water-entry points in fields with high water cuts, well intervention costs could become prohibitive to contemplate.
Instead, a conventional concentric coiled tubing (CCT) string can be transformed into a specialty CCT by adding an encapsulated single-conductor wire inside. The string can then be run with a modified vacuum bottomhole assembly and a logging tool to achieve production analysis and logging simultaneously.
Combining these two proven technologies into one solution is an economical way to produce the wells via the CCT and its vacuum BHA while logging the well in one run. It has economic benefits to operators by eliminating the high cost associated with installing dual completions and dual wellheads. It also enables logging in 7- and 4 ½-in. cased holes that were not accessible for production logging using prior technologies.
This paper will describe the revolutionary technology and case histories along with lessons learned. It will also describe in particular the applications of the technology for high-producing water wells.
Understanding Reservoir Quality Indicators in Marginal Marine Environment: Integrating the Advanced Wireline Measurements in Niger Delta
Authors: Cavalleri Chiara , Claverie Michel , Shrivastva Chandramani , Ossai Okechukwu 
Published: October 2013

Abstract
The Tertiary marginal marine clastics reservoirs offshore Nigeria have traditionally been treated as well-characterized for formation evaluation; however, reservoir distribution and quality could be quite variable due to the heterogeneities that went unnoticed. Reservoir sands in the study area are structurally controlled and depositionally complex due to various sub- environments architectural elements contributing to the pay zone. Different sands are analyzed with advanced wireline measurements of tri-axial induction resistivity, nuclear magnetic resonance and dielectric dispersion, in the background of geological understanding developed in nearby wells with borehole images. We also describe the new understanding of reservoir rock quality and producibility in a field where easterly dipping massive sand units are juxtaposed with thinly- bedded shaly sand units in a composite interplay of depositional processes.
The data are interpreted taking into account that both the sands and the intermingled shales are anisotropic. Thinly bedded reservoirs, which had been previously overlooked, are discovered and added to the reserves estimate. By reviewing magnetic resonance fluid maps recorded at different and deeper depths of investigation, the radial distribution of fluids is mapped in both massive sandstone and thinly laminated sections.
The data are further analyzed to characterize a set of innovative producibility indicators derived from the logging data. These include: invasion profile, high resolution volumetric analysis using sand and shale definition from image logs, irreducible water analysis and movable fractions from dielectric dispersion, and magnetic resonance T1, T2 and Diffusion measurements.
Different sand units are studied with these indicators, and heterogeneity is captured and addressed to resolve for more precise reservoir summation. Comparison with well test results validates the improvements in reservoir description from multiple high resolution logging measurements (at early stage of reservoir development) into reservoir models.
Study on Undulating Well in Anisotropic Reservoir by Semi-Analytical Method
Authors: Han Guoqing , Zhang He , Ling Kegang , Zhang Rui 
Published: October 2013

Abstract
To maximize the production rate and develop marginal/unconventional fields, all kinds of intelligent wells have been proposed and practiced in field, including multi-stage fractured horizontal well, multi-lateral or fishbone completions. Undulating horizontal well, also called snaky well, is one of the most common intelligent completions nowadays.
This paper presents a semi-analytical model for undulating horizontal well, which predicts not only the inflow from reservoir and pressure drop inside the wellbore, but also takes into account the interference among well segments. As the undulation index and cycles increase, the undulating completion can result in a good effective vertical permeability and inflow. Although the advantage is marked, the related technical challenges and high cost are increased correspondently. Thus, an optimization of the undulation index and cycle is required to maximize the project Net-Present-Value (NPV). Along with appropriate economic analysis, the proposed semi-analytical model can suggest and evaluate the field development in a time manner. Further, the undulating well can be a substitute for multi-stage fractured horizontal well, especially for dual porosity shale gas/oil fields.
Pushing the Boundaries: Tapping "Hard-to-Reach Oil" by Drilling High-Angle Deviated Wells
Authors: Bardalaye Jayanta , Al-Azmi Khalid Huomood , AL-Azmi Mohammed Saad , Belal Dawood Salman , Mudavakkat Anandan , Mukherjee Pradip Kumar , Al-Sabea Salem Hamad 
Published: October 2013

AbstractThe Greater Burgan Field is the oldest producing oil field of Kuwait. Till date, more than 1200 wells have been drilled in the field. Construction of surface production facilities, power line corridors, roads as well as office and housing complexes for its employees have put severe constraints on surface locations for drilling new wells. A fault block in the Ahmadi ridge that was expected to be geologically very prospective for hydrocarbon accumulation could not be accessed for a long time as it was below the Kuwait Oil Company's office complexes. Structural complexity and poor quality of seismic data around that area also added to the uncertainty.To reach the producing Wara and Burgan sands, the wells have to be drilled through the carbonate Dammam, Radhuma and Tayarat formations which are potential loss zones – more often than not leading to total mud loss. Deviated wells drilled so far in the field were, therefore, restricted to a maximum inclination of 45 degrees with the kick-off point located as deep as possible to minimize losses. This put a severe constraint on the horizontal drift achieved at pay zone level.Two high-angle deviated wells were successfully planned and drilled with inclinations of 50 degrees or more with shallow kick-off depths to achieve a horizontal drift of upto 1 km to reach the hydrocarbons locked up below the company office complexes. The higher inclinations also helped in maximizing the reservoir contact and net pay of more than 100 ft was encountered in both the wells.
Value Generated through Automated Workflows Using Digital Oilfield Concepts: Case Study
Authors: Al-Enezi Badriya Abdulwahab , Al-Mufarej Mishal , Anthony Elred Rowland , Moricca Giuseppe , Kain Jeff , Saputelli Luigi 
Published: October 2013

Abstract
With the goal of reducing non-productive time (NPT) and increasing operational efficiency, KOC decided to implement pilot projects to evaluate feasibility of intelligent digital oilfield (iDOF) concepts. The Kuwait integrated digital oil field in the Sabriyah field (KwIDF Sabriyah) pilot was implemented as a tool for real-time collaborative diagnosis and optimization of a water-flooded giant carbonate reservoir within the Sabriyah field.
Initiated in 2011, KwIDF Sabriyah is currently extensively used for the monitoring and optimization of (a) waterflood, (b) electrical submersible pump (ESP), and (c) gas lift (GL) systems. KwIDF Sabriyah has increased the operational efficiency in many areas of daily engineering activities, including (a) reduction of excessive time spent on data acquisition and validation, (b) significant reduction of time on the identification of the root of failure of equipment, (c) collaborative decision-making with key stakeholders, (d) minimization of time between decision to execution by means of operations support services, and (e) prompt re-evaluation of optimization initiatives soon after implementation.
This paper illustrates how the automated workflows are used by describing a typical working day at the KwIDF Sabriyah Collaboration Centre (CC) where the visualization of real-time well production parameters are provided to an integrated multidisciplinary team consisting of reservoir, production, process and well surveillance engineers. This environment supports the cooperative and proactive decisions never before achieved while functioning, not only in physically remote locations, but also in departmental silos within the company. An extensive case history is also provided to illustrate the new way work is being achieved and how it is adding value with ease, with the support of KwIDF Sabriyah workflows platform. The achieved results are reported in terms of sustained oil gain.
Kuwait Oil Company Devised a Customized & User Friendly Web Based Incident Investigation Module through HSE Live
Authors: Al Qattan Fahad , Alam Mohammad Aftab , Haque Mohammad Rashidul 
Published: October 2013

Abstract
During the year 2011-12 the Company had 487 incidents out of which 92% were of minor nature. As per Company procedure all incidents must be investigated. Accordingly all moderate & major category incidents are investigated whereas same is not the situation for minor incidents considering its large number; which require time & resource for proper investigation. It is a fact that minor incidents are indicators of moderate & major incidents demanding essential investigation of minor incidents to prevent moderate & major accidents.
Consequently with customized & user friendly approach, a web based module for incident investigation was developed in house through ‘HSE Live’ an online incident reporting & data management tool. Module is customized to KOC Incident Investigation & Corrective Action Procedure converting Comprehensive List of Causes into a web based application. Application takes into account the main constituents of immediate & root cause such as - Unsafe Act, Unsafe Condition, Personal Factors & Job Factors. Each potential cause has 6 different probabilities and each probability enquires about 7 likely situations. Module assists investigators in managing entire investigation process starting from formulation of investigation committee, identifying immediate cause & root cause, recommendations, action items, till generation & issuance of investigation report along with follow up action.
The utility of web based application was tested for an online actual reported incident utilizing the test server of HSE Live Portal. Subsequently the application was demonstrated before HSE Leadership and further upgraded considering their valuable suggestions.
Internally developed web based incident investigation module is a unique and innovative tool which is totally customized, extremely practical as well as user friendly. The paper shall demonstrate a typical but realistic web based application for incident investigation with optimum use of time and resource aiming prevention of incident recurrence.
Understanding the Key Parameters in Optimization of Steamfloods in Heavy Oil Fields with Application on SPE Comparative Solution Project
Authors: Temizel Cenk , Purwar Suryansh , Dursun Serkan , Hancioglu Baris 
Published: October 2013

AbstractHeavy oil has gained significant attention and importance recently because of a multitude of reasons—growing demand of oil from developing economies, declining availability of easily recoverable or "conventional" oil, and significant advances in required technology. Even though the current estimates of heavy oil in place are three times that of conventional oil, they have only recently become economically viable because of sustained high oil prices. Improved technology has also driven down the recovery risk to minimal levels. The earliest recovery methods for heavy oil were largely cyclic stimulation, with steamflooding gaining acceptance in the 1970s. Despite other thermal and non-thermal recovery methods for heavy oil, steamflooding remains the most widely used technology. Current production by steamfloods alone totals more than 1.1 million BOPD.Previous studies have established how steamfloods are affected by parameters, such as rock properties, oil composition, degree of steam override, sweep efficiency, steam quality, and steam injection rate. However, the capital-intensive nature and low profit margins of the steamfloods mean that each field development decision is crucial and the oil recovery and margins are much more susceptible to uncertainties in oil price, well performance, facility costs, and subsurface parameters.While studies have been performed to corroborate the effect of subsurface parameters and economic uncertainties separately, there has been little advancement in terms of coupling all of them together in one unified study. In this paper, the effects of uncertainties on project net present value (NPV) are studied by coupling numerical reservoir simulation; a design- of-experiments based approach to handle uncertainty, an established economic model, and a commercial optimizing tool to determine the optimal field operating variables.
Heterogeneity Index and Fast Screening Processes Used in a Large Mature Field Designed for Quick Production Gains
Authors: Harami Khalid , Bolanos Nelson , Sharma Siddhartha , Slimani Karim , Abdel-Basset Mohamed , Pimentel Jose Antonio , Kiome Patrik , Rodriguez Jaime Alfonso , Al-Ajmi Moudi , El Doushy Ahmad , Al Mufarrej Mishal 
Published: October 2013

Abstract
The Heterogeneity Index (HI) process was utilized in order to demonstrate production gain opportunities in a very short period of time, in a large mature ME field with around 500 wells producing from different reservoirs. The HI process provided a quick screening method of identifying preliminary candidate wells with anomalous behavior (over/under performance) for further analysis and most importantly, provided the foundation for the overall Structure Production Approach.
This process; HI, can be calculated by utilizing OFM. A Cross Hair Plot has also been utilized to show the comparison of the HI of two variables in the same plot, creating an easy way to identify wells behaving differently from the average. The cross hair plot can be combined with X-Y Coordinated plot which reproduces the location of the wells.
The results from this screening tool were utilized to identify the families of productivity problems at field level, and additional fast screening was done at well level to identify candidates for production enhancement. Representative Wells were selected for detailed diagnostics based on the relevance and size of productivity impact and, the potential of its production rate or well deliverability.
Once a few "top potential" wells were identified, production engineering workflows were implemented in order to assess and forecast the potential of production incremental and try to determine and evaluate the best probable action.
Some of the key innovate workflows used to complement production enhancement were: Time- lapse nodal analysis (honoring production history and neighboring wells), rate transient analysis (to consume sporadic/low frequency production data), single wellbore modeling (based on logs and flow units), among others.
This paper will demonstrate the Production Enhancement Technologies Methodology, in particular the HI process with real examples; pending on data release approval from the owner and the progress of the operations.
Managing Technological Complexities in Oil & Gas EPC Projects
Authors: MOSSOLLY Mounir 
Published: October 2013

AbstractContemporary research in Project Complexity suggests that Project Complexity is considered to be split between two major orientations: Organizational Complexity and Technological Complexity. This paper addresses the Technological aspect only, with special emphasis on Oil & Gas EPC projects. The aim of this paper is to define and illustrate the aspects of technological complexities and thus understand how to better manage them. Technological complexity might be a source of risk in project execution and needs to be properly managed to mitigate such a risk. Management process of technological complexities is similar to managing risks in projects in terms of procedural steps, but it is not the same. Technological complexities shall be tackled taking into consideration that they actually exist or do not exist rather than just having a probability of existence as is the case for traditional project risks. Contrary to what might be thought; technological sophistication is not a source of technological complexity, simply because if a certain technology is availing and is proven to be workable, no matter how sophisticated it is, its complexity level is considred to be low. This paper suggests a method of measuring technological complexity level for determining its real weight. Once the technological complexity is measured, proper level of attention can be given to it, including the allocation of necessary resources for managing it. Manging technological complexities in Oil & Gas EPC Projects shall be a joint effort between various project stakeholders, each according to his relevant scope. This paper also suggests some best practices for dealing with the ever growing technological complexities in Oil & Gas EPC Projects.