bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Integration of Innovative Technologies Enabled Operator to Drill and Complete First Horizontal Well in Depleted Shale Inter-bedded Limestone Reservoir in Pakistan - A Milestone Achieved.
Authors: Siddiqui F. I. , Naseem M. O. , Khan F. B. , Asrar M. 
Published: December 2014

Abstract
The name "Sui" has become synonymous with natural gas in Pakistan on discovery of the first well in 1952. Sui is Pakistan Petroleum Limited's (PPL) flagship gas field and is one of the major contributors in meeting the energy demands of the country since its inception. Two major reservoirs of this field are the Sui Main Limestone (SML) and Sui Upper Limestone (SUL); both of which have become highly depleted over time.
Pakistan is striving to meet its growing energy needs and is making all possible efforts to enhance production. Operator successfully drilled one horizontal well in the Sui Main Limestone in underbalanced conditions and planned to drill the FIRST HORIZONTAL WELL in the SUL reservoir to enhance production of the field. Drilling a horizontal well in this formation with conventional drilling techniques was a high risk task due to depleted reservoir with shale interbedding, complete loss of circulation, hole instability and reservoir damage issues which altogether made it almost impossible to complete the well.
The operator took this challenge to implement innovative technologies to mitigate all hazards and meet objectives. Drilling and reservoir related problems were identified in detail. A comprehensive Geo-Mechanics Study was conducted to define the safe drilling window of the SUL Reservoir. To maintain bottom hole pressure within the defined drilling window, further integration of Multiphase Fluid Drilling (Membrane Nitrogen & Water Based Mud) and Electromagnetic Measurement While Drilling tools along with real time ECD (Equivalent Circulating Density) and Gamma Ray monitoring Sensors were selected. A major challenge for the operator was to complete the well in the same reservoir conditions which was accomplished by applying Downhole Deployment Valve Technology with 9-5/8″ casing.
This paper will elaborate the details of planning and execution strategies to complete this challenging project. The application of these innovative technologies represents a step change in improving Operator's ability to exploit mature reservoirs, especially those that are severely depleted like the Sui Gas Field and also for the Oil & Gas Sector in Pakistan.
Simultaneous Operations for ADCO and Al Hosn at Shah Field
Authors: Kamran Ali , Kumar Chinculi Rajeev 
Published: December 2014

Abstract
Al Hosn Shah Gas (AHG) Development Project on-ground activities commenced in Shah Field during last quarter 2011.
Some of the major activities of AHG Project in Abu Dhabi Company for Onshore Oil Operations (ADCO)-controlled 40 km2 areas were: Initial demarcation and handover of the AHG well pads (eight locations)Movement of rigs, etc. to AHG well padsLaying of more than 50km length 16" & 20" diameter pipelines between the AHG pads and to the main Gas PlantProvision of Right of Way and berms for various pipelinesProvision of 11kv transmission linesConstruction of a new 25 km black top roadConstruction of Etihad Rail line, crossing ADCO Main Oil Line and Rig Route
Numerous ADCO live flow lines, 33kv and 11kv overhead transmission lines and underground network of communication and instrumentation cables were already present in these areas of AHG activities.
The mere safe handling of transporting men, machines and materials through all the above-mentioned live networks to various sites was an achievement in itself. It was a big challenge to protect and keep in service all the ADCO facilities throughout the AHG project. The main AHG project activities spanned a period of almost two and a half years.
A big logistical and social exercise of re-locating ADCO Shah and relevant service contractor personnel from ADCO Shah Camp was carried out in order to protect them from potential exposure to H2S and SO2 during flaring for AHG wells cleaning.
ADCO Shah Full Field Development (FFD) Project also took place in the same time frame. FFD was implemented in the locations where previous live facilities were already in operation. Apart from upgrading the Process Stations, instrumentation on most of existing wells was included in the FFD scope. The simultaneous supervision of these projects in brown fields is a testimony to the remarkable vigilance and hard work by ADCO Operation personnel.
This paper summarizes the ways and means through which the Simultaneous Operations (SIMOPS) management has resulted in a safe and smooth handling of all these activities, while outlining the plans for future parallel operations of the two OPCOs.
Cryogenic Tanks Re-Certification - Case Study
Authors: Adamou Adib Soufiane 
Published: December 2014

Abstract
Liquefied Natural - Petroleum Gas are usually stored by especially low temperature tanks, with different design configurations developed in the industry using steels with specified low temperature properties. This paper gives an overview on the properties, and behavior of the 9 %-Nickel-alloyed high strength steels for low temperature applications. These steels have been recognized by the ASME code for cryogenic use since 1954 and has been widely used for LNG storage in competition with stainless steel, other austenitic alloys and aluminum.in fact, austenitic stainless steels are used in cryogenic applications and can be used for building smaller storage tanks, but large containment vessels are usually welded from 9% nickel steel because of expense considerations. This technology is well-established worldwide. The first part of this paper is focused on the 9% nickel steel, its properties and, use in the LNG storage tanks.
The different LNG tanks design generations, their particularities will be described. A general overview of LNG tanks failures recorded in the industry will be presented as well.
Inspection, repair and alteration of atmospheric tanks designed according to API 650, are well covered with the API 653 standard, unlike the cryogenic tanks generally designed according to API 620 or BS 7777, no standard exists to cover the inspection, repair alteration requirements - when applicable - to recertify these tanks.
The document provides a benchmarking of different cryogenic tanks in terms of operation life and type of containment (single, double containment tanks) in the LNG industry. Different options are addressed in order to recertify these tanks are adopted in the industry will be detailed.
ADGAS operates three double walled tanks, reaching their design life. Longevity study was undertaken in order to re-certify the tanks based on different studies, inspection / operation / Maintenance history. Main outcomes of this study will be presented.
Data Acquisition and Appraisal Activity Challenges in Green Fields within a Remote Area - Case History from a Carbonate Reservoir
Authors: Akl Osama , Metwalli Magdy , Radwan El Sayed , Elbekshi Amer , Al Marzouqi Mohamed , Bin Kuwair Husam F. 
Published: December 2014

Abstract
This paper describes the frame work and new concepts implemented for appraisal data gathering from two undeveloped green oil fields (Fields-A and B) as shown in Figure-1. Acquired data program was a heavy schedule, involved testing of multiple wells, integrated by different teams to full fill all requirements which are vital for field's development. Limited resources, HSE and environmental issues, remote/unmanned areas, heavy testing facilities, rig & rig-less resources and difficult topographic nature of these areas are part but not all of the challenges faced to implement the appraisal data gathering program to achieve the program objectives. An integrated workforce team was formed from different disciplines, project partners and all stakeholders succeeded to set an innovative scope of work, plan, procedures and distribution of responsibilities for each partner to overcome and trouble shoot these problems. The appraisal data gathering approach resulted in completing the appraisal program successfully as per the time line plan, obtained high quality of huge data, adhering to high safety operating procedures and standards at economic value.
One of the major challenges was to avoid flaring of oil and risk of transporting huge quantities of crude oil produced during the long term production testing operation & risk of exporting by trucks to far locations at distances of around 130 Km from the source to store in other wells. Water handling during the injectivity test was also a big challenge. Safety operation related risk of high vapor pressure and flash point either in testing facilities or while loading and transportation in high temperature. H2S and SO2 are other issues. Proper planning, team work, risk assessment and mitigation plans, responsibility allocation the appraisal project was successfully completed in shorter time than expected and all objectives were met and obtained Shareholders gate approval to proceed with fields development in cost effective manner without any hazardous or fatalities.
Getting to Effective Solutions Instead of Blame - the Impact of the Human Factors and Classification System HFACS Approach
Authors: Cooke Steven J. 
Published: December 2014

Abstract
Effective corrective action has always depending on the correct and accurate identification of the real problem to be fixed. Investigation of system deficiencies and development of corrective action processes have evolved over the decades from "experience-based" expert teams (internal or external) to formalized methodologies than can be applied with a basis of training and moderate field experience. All formal Quality Management Systems (ISO-9001, ISO/TS 16949, AS 9100, Six Sigma) outline requirements for both correct investigation and documented corrective action. However, the best methodologies are not defined, leaving the success of these processes subject to significant variation. A plethora of Root Cause Analysis (RCA) methods are available, all based on the principles defined as early as 1905 in the Lancet article "The Present State of Medical Practice in the Rhondda Valley"1, and expanded in "Definition of a Root Cause" by Mark Paradies in October 20052. In the culmination of its development from 1985 in the development of the TapRoot® RCA method. As stated in the American Society for Quality (ASQ) book, "Some root cause analysis approaches are geared more toward identifying true root causes than others; some are more general problem-solving techniques, while others simply offer support for the core activity of root cause analysis."3
After years of experience with different levels and definitions of investigation procedures and corrective and preventive action (CAPA) activities, ADGAS recognized the need for a more objective and precise identification of systemic problems that were manifest in the continuing failure of individual action plans. A formal Root Cause Analysis (RCA) procedure and training were implemented to improve the investigation phase, but the systemic root causes remained elusive. Further research into behavioral safety led to the seminal work "The Human Factors
Analysis and Classification System–HFACS" by Scott A. Shappell of the FAA Civil Aeromedical Institute, February 2000.4 The HFACS was developed to address faults in highly-critical industries such as aerospace and military readiness, and has been adopted successfully by many other organizations. ADGAS has modified its Root Cause Analysis process to incorporate the HFACS at the "contributory cause" level. This change from the more simplistic assignment of "operator errors" has removed the assumption of blame to an improved understanding of the actions that can be taken by the company to prevent errors. The significance of the formal linkage from operator actions to corporate policies and structure cannot be overstated. A description of the HFACS and how it has been applied to improving asset Integrity and Reliability in ADGAS will be presented.
A Risk Based Approach for Prioritizing Electrical Equipment Replacement and Repair
Authors: Cayanan Christopher , Navarro Rey , Wagner Ernest 
Published: December 2014

Abstract
Electrical infrastructure equipment in the petrochemical and/or oil and gas industry in North America is generally 40 or more years old. The life and reliability of electrical equipment in this age range can be compromised due to operating conditions such as exposure to moisture and chemicals, loading, temperature, vibration, and mechanical stress over the life of the equipment.
Electrical equipment operating and life cycle philosophies tend to vary from age based replacement to run-to-failure. This results in an ad-hoc approach for determining the appropriate time for equipment replacements or major repairs. Limited resources, funding, and other competing projects exacerbate the issue.
An operating and life cycle management philosophy using preventive and predictive maintenance results to prioritize equipment replacements and/or improvement will help optimize how to determine when equipment repair or replacement is justified.
This paper will describe a systematic risk based approach of prioritizing electrical equipment replacement and repair projects to improve electrical reliability and safety. The approach uses probability and consequence techniques for equipment repair or replacement.
Maximising Enhanced Oil Recovery Opportunities in UKCS Through Collaboration
Authors: McCormack M. P. , Thomas J. M. , Mackie K. 
Published: December 2014

Abstract
The UK Continental Shelf (UKCS) is one of the most mature offshore basins in the world. Achieving optimal recovery from the basin is demanding, but as the anticipated ultimate recovery factor is 46% (1) of oil initially in place, there is still significant opportunity to optimise recovery from the existing oil fields. PILOT, a partnership between the UK Oil and Gas industry and the UK Government, has been re-focussing its efforts on maximising North Sea recovery.
There are currently only two Enhanced Oil Recovery (EOR) schemes operational within the UK North Sea. The principal barriers to implementing EOR projects are believed to be (1) incomplete subsurface understanding; (2) supply of secure, low cost injectants; (3) the challenge of implementing EOR retrospectively on a brownfield site; (4) concerns over project economics.
The PILOT EOR Work Group was set up in 2012 to co-ordinate industry and government attempts to tackle these challenges. A three phase programme was identified to: (1) systematically screen the UKCS fields for EOR potential; (2) engage industry and look for synergies and collaborative opportunities to progress EOR understanding; (3) where possible, initiate new EOR projects with operators.
The UKCS EOR screening exercise confirmed that there is still a significant realistically achievable EOR prize of up to 1 billion barrels of oil. The second phase of work focussed on developing collaborative ways of working to tackle the technical and commercial challenges associated with EOR projects, with particular focus on offshore ‘brownfield’ environments. Three EOR techniques were progressed and high graded on the basis of their prize and do-ability in an offshore environment: (a) Low Salinity Waterflood EOR; (b) Chemical EOR; (c) Miscible Gas Injection. Industry workshops were held for each EOR type and prioritised work programmes were implemented via operator "clusters", facilitated by the PILOT EOR Work Group. Examples of deliverables include (i) generation of a low salinity coreflood protocol to ensure that laboratory studies are performed in a consistent manner; (ii) initiation of a Joint Industry Project and an industry call for proposed facilities solutions for implementing low salinity on brownfield platforms; (iii) identification of industry resource to support UKCS operators with planning of chemical EOR opportunities. Successful completion of these collaborative activities will increase the chance of implementing further EOR schemes in the UKCS, unlocking the significant EOR prize.
Developments on Relative Permeability Computation in 3D Rock Images
Authors: Arrufat Tomas , Bondino Igor , Zaleski Stéphane , Lagrée Bertrand , Keskes Noomane 
Published: December 2014

Abstract
Digital Rock Physics (DRP) is commonly perceived as a range of technologies finalized at the calculation of properties of interest to geophysical, geological and reservoir engineering disciplines starting from 3D high resolution x-ray micro-CT images. Provided that verified, physically validated and controllable image acquisition and modeling workflows are available, petrophysical properties computed in this way can in theory be used in association to traditional difficult-to-obtain or often scarce core laboratory measurements to achieve higher insight of the reservoir and reduce the uncertainty in both static and dynamic models. DRP's potential for the industry is also expressed by the possibility of achieving better understanding of recovery mechanisms by probing fluid distributions at the pore scale, as is being nowadays investigated thanks to the utilization of miniaturized flow cells in micro-CT set ups or synchrotron facilities. This could be key for optimization of EOR processes.
From the point of view of operating companies, most efforts are still deployed in the R&D Lab with deployment of the technology in operational context still at its infancy and hindered by the issue of representativity of the microscopic imaged or computed scales (or image resolution-scale trade off), by the difficulty one has to unambiguously inform pore scale models with a sufficiently limited but precise set of physico/chemical information and by lack of robust validation procedures. In this dynamic and improving context, we update on our R&D efforts to evaluate and test one particular technology for the simulation of multi-phase flow in digital rocks, the Volume of Fluid method embedded in Paris simulator: the objective is to verify the potential interest in the medium and long term, knowing that other simulation technologies, being simpler to apply, are more mature for utilization in today's context. In this work Paris simulator is utilized to compute single and multi-phase flow properties on TOTAL's supercomputers for both a sandstone outcrop sample from Scotland and two carbonate rocks from UAE. First the simulator is tested for simpler permeability computations and benchmarked against a Lattice-Boltzmann solver; then the code is used for two-phase flow and for relative permeability computations. It is concluded that the particular simulator used in this work, still under development, can be used for different rock types and is particularly efficient in HPC environment: it has therefore strong potential. We conclude describing the future steps of development that will be needed to make the simulator applicable for digital petrophysics.
Assessment of Reliability of Cement Bond Evaluation with Some Interesting Field Case Studies
Authors: Ashena R. , Thonhauser G. , Dianati D. 
Published: December 2014

Abstract
High numbers of lack of hydraulic zonal isolation and occurrences of numerous high annulus pressure problems in wells in Middle East which has led to more remedial cementing and also workover rig days, has encouraged the industry to consider more efficient cement bond evaluation methods and discriminate between zonal isolation and cement bond log interpretation.
Therefore, in this paper the effects of the important parameters on cement bond logs including casing size, well deviation, type of fluid, and mud weight during the logging operations, surface applied pressure and microannulus, fast formations, type of formation, tool eccentricity, casing eccentricity, multiple casings, pressure and temperature, effect of cementing operations have been considered and the cement bond reliability has been discussed.
In this study, by presenting interesting examples of different cement bond logs, a comprehensive assessment of different cement bond log evaluation methods (conventional CBL/VDL, Radial CBL/VDL, Ultrasonic logs like segmented bond logs, isolation scanner in multiple casing scenario) have been performed which shows sonic cement bond logs are under some reliability risks and may not be always descriptive of zonal isolation. As ultrasonic tools outperform sonic ones, they are suggested specially wells with special cases.
Bravo Dome Subsurface and Surface Network Modeling
Authors: Nezhad Shahin , Williams Craig 
Published: December 2014

Abstract
Bravo Dome is a CO2 field in northeastern New Mexico State of USA which has been developed via more than 700 wells and approximately 600 miles of pipelines and flowlines. Nearly three-decades of CO2 production from the field have reduced the reservoir pressure from 350-400 psia to approximately 150 psia.
To explain wellhead pressures and the pressure drops along the pipelines which transfer the produced gas to the central plant, a combined subsurface and surface network model for evaluating the effects of reservoir, wells, flowlines, pipelines and compression plant performance and operational constraints has been developed to support further development and facilities modifications. The developed tool simulates CO2 movement all the way from the reservoir to the compressor station inlet.
The reservoir simulation model, built in VIP, was history matched based on reservoir and wellhead pressures. The surface network was built using Nexus. Historical and current operating conditions (wellheads pressure, node pressures and plant inlet pressure) were matched in the combined tool using pipeline and flow line roughness, WGR and "real" inside diameter of pipelines.
This approach identifies the potentials for improving the field performance of low-pressure gas fields. It encourages bottlenecks' identifications in complex surface networks and also brings ideas for facilities' modifications for enhance hydrocarbon recovery and field re-development.
Application of ‘Unified Fracture Design’ to Higher Permeability Reservoirs
Authors: Jangda Zaid Zaffar , Al-Nuaim Sami 
Published: December 2014

Abstract
Hydraulic Fracturing treatment design as classically used in the industry is based on the optimization of fracture geometry. However, the Unified Fracture Design (UFD) concept, allows hydraulic fracturing treatment design based on dimensionless fracture conductivity; with the best variable to characterize the size of fracture being the volume of proppant placed in the ‘pay’ rather than length and width, as the fracture geometry that would maximize production is unique for a particular mass or volume of proppant.
The purpose of this work was to design an effective and economical hydraulic fracturing job using UFD by selecting the amount of proppant that results in optimal treatment sizing, at which the Net Present Value (NPV) of incremental revenue balanced by treatment cost is maximum. This included selecting the appropriate proppant number which would give the best productivity index while the chosen proppant volume is placed according to the optimal dimensionless fracture conductivity.
Without going into the details of fracture mechanics, fluid rheology and reservoir engineering, the fracture treatment was designed by taking basic decisions in an iterative manner through an in-house developed program that can be used for any sort of reservoir. A real field case with medium permeability was chosen for optimization which resulted in a very high NPV value with the selected proppant design.
This work has great scope in designing hydraulic fracturing job using different kinds of proppants for different permeability formations, not restricting the applicability to low permeability formations.