bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of Robust ICD Designs to Provide 30 Year Life by an In-Depth Qualification Program
Authors: Edmonstone Graham F. , Kofoed Curtis W. , Mayer Christian S. , Troshko Andrey A. , Jackson Matthew S. 
Published: November 2016

Abstract
Following a premature failure of an ICD liner in a pilot ERD well in a giant Middle East offshore oilfield, a thorough investigation, summarised in a prior paper1, 2, was undertaken to understand the failure mechanism. The conclusion of the failure analysis was that high shear flow from the ICDs accelerated tubing corrosion leading to a complete penetration of the tubing wall in the vicinity of the ICDs.
This paper details the subsequent work undertaken to initially review existing ICD designs currently available from the market to deem their suitability to withstand flow induced corrosion. Initial review of current designs led to the need for subsequent development of improved ICD designs, also detailed in this paper, that could withstand flow induced corrosion, as well as accommodate heightened production (400 - 1,600 psi) and stimulation (1,000 - 2,400 psi) differential pressure requirements.
In particular the paper will cover the below areas of qualification, with key outcomes: Engineering design review of existing, improved and new ICDsCFD analysis for flow-induced corrosion hotspot identificationIntegrity testing for production and stimulation scenariosFlow performance and minimum back pressure requirement testingErosion testing of the entire ICD assembly
For any of the designs to be suitably qualified, they had to systematically and successfully pass the aforementioned five areas, which in summation is believed to be the most in-depth qualification program undertaken in the industry to date. It has also likely developed the most robust ICD designs to date affording the ability to operate under heightened production and stimulation conditions while still providing the required 30 year life for use in a giant Middle East offshore oil field.
Injectivity Enhancement From Back Flowing of Water Injectors
Authors: McNeilly K. , Al-Shamsi A. R. , Khan M. N. , Al-Blooshi J. R. , Husain A. 
Published: November 2016

Abstract
Allowing a water injector to flow (also known as "backflowing") for periodic periods after injection has been identified as an opportunity to quickly and cheaply improve injection rates. Data collected from 21 water injectors in a giant offshore carbonate reservoir in the Arabian Gulf indicates an average injectivity improvement of 53% can be achieved (equivalent to an average gain of 987 bwpd per well) when comparing the injection rates before versus after the backflow event.
Decreasing injectivity has been seen in some water injectors in the field. The cause of this decrease is suspected to be caused by suspended solids/particulates in the injected filtered seawater causing formation damage or plugging of the perforations. Acid re-stimulations have historically been used to dissolve these damaging particulates to reduce the skin and improve the well injectivity. However, the conclusion that will be presented in this study is that backflowing water injectors is an additional tool that can be used in the operational toolkit to remove this near wellbore damage and restore a significant amount of the lost injectivity.
Given the high cost, logistical requirements, and environmental impact of acid stimulations an alternative approach to improve injectivity by backflowing the water injectors was investigated. Backflowing operations have been proven to provide a significant improvement in injectivity while only requiring a short duration, limited operational requirements, and small cost. The periodic backflowing of all water injectors should be considered as an operational best practice for the field in the future.
Public Safety and Sour Gas: A Case Study of Innovations in Public Protection and Emergency Response
Authors: Daher Elie , Ziarati Amin 
Published: November 2016

Abstract
A key Oil and Gas player required hydrogen sulfide (H2S) safety solutions for their project in Iraq. The operator had planned a drilling operation on a rig with a high potential concentration of H2S. They realized that they needed to protect and secure two communities that consist of more than 1500 homes near the drilling site from a potential gas release. The mountainous location and tough winters required a reliable, portable and robust detection and communication system that would work in extreme weather conditions with temperatures ranging from -15°C to 52 °C. The two villages were located 5km from the worksite. The operator needed to make sure the villagers are notified of any gas readings that may pose hazards to the communities.
A cutting-edge community protection solution was implemented composed of several gas and environmental monitors linked together to control the conditions within the EPZ. The innovative perimeter monitoring solution allowed environmental conditions to be monitored online in real-time. Due to difficult terrain conditions, boosters were deployed to enhance the connection between the perimeter monitoring system and the base station.
Radio-frequency (RF) and web technologies were integrated into each platform to enable real-time transmission of data to the base unit. From the base unit, the stored data is the uploaded to a global server. This was designed in such a way to give the operator a comprehensive understanding of all the stored information.
The use of a proprietary SCADA system provided a reliable and accurate data log which could be stored and accessed online. Notifications on impending low battery life, wind speed, and direction, temperature and gas readings were provided on a real-time basis, thus helping the operator to make informed decisions to protect its assets and the community, prior, during and post any event.
A C02 Foam Conformance Pilot in US Gulf Coast Region
Authors: Chabert M. , D'Souza D. , Cochran J. , Delamaide E. , Dwyer P. , Nabzar L. , Lacombe E. 
Published: November 2016

Abstract
The use of foams for gas floods conformance control attracts a renewed interest in recent years. Nowadays, despite the low oil price environment, some foam EOR projects remain active both at lab and pilot scale. Indeed, such applications have the potential to not only improve the oil rate, but may also reduce costs associated with gas injection and cycling. In other words, foam can increase gas injection efficiency both in terms of oil production and of gas consumption.
In this paper, we describe the design of a dedicated foaming formulation and its application in a CO2 foam pilot in a CO2 flood in the US Gulf Coast. The main hurdle for formulation design was the use of a high salinity and hardness production water for chemicals injection. Our experimental approach to overcome this challenge was based on successive steps, comprising automated solubility evaluation of multi-component formulations, adsorption measurements, foam stability evaluation and finally corefloods in reservoir conditions. Following this lab work, we carried out the foam injection pilot on a 40 acre, 6-well flood pattern consisting of three injectors and six producers. Conformance rather than indepth mobility control was targeted, and a relatively low foam volume representing 1% pore volume of the pattern was thus injected. The treatment was applied as three alternating slugs of aqueous foaming solution and CO2 over a period of four months, with the aim of generating foam in-situ in the near- wellbore area.
Strong foam formation in the near-wellbore was evidenced by a strong drop in CO2 injectivity after each surfactant slug. Injectivity then slowly recovered, with a slower recovery as a function of the slug number, indicative of foam propagation deeper in the reservoir. Injection logs showed an efficient diversion of CO2 from thief zones to previously poorly swept reservoir intervals. On the production side, although much less CO2 was injected, oil rate was relatively constant, exhibiting little decline. We interpret this as a consequence of the injected CO2 flooding new reservoir zones with higher residual oil saturation. Overall, the strong decrease in CO2 consumption at a relatively constant oil rate translates into a noticeable increase of the injected CO2 efficiency.
This paper describes the formulation design and the foam pilot implementation in challenging conditions, in particular with regard to salinity and hardness of the available injection water. It qualifies foam as a straightforward, low risk conformance method. Indeed, besides potential increases in oil rate, the enhancement of CO2 injection efficiency demonstrates the success of this application.
Development of a Giant Carbonate Oil Field, Part 3: How to Build Enhanced Oil Recovery Development Plan Aiming for 70% Recovery
Authors: Kumar Jitendra , Nakashima Toshinori , Draoui Elyes 
Published: November 2016

Abstract
The considered giant carbonate field is located offshore Abu Dhabi and has 50 years of production history through a series of pressure-maintenance methods. Chronologically, the implemented development approach includes gravity-driven dumpflood water injection, peripheral water injection, and immiscible crestal gas injection and a review of these methods is discussed in Pavangat et al., 2015. Since, the historical pressure maintenance methods are approaching its limitation in sustaining the production; a gradual migration towards sweep-oriented pattern development is required to further extend the plateau and is discussed in Nakashima et al., 2015. The pattern-based Improved Oil Recovery (IOR) not only extends the plateau and recovery but also set the stage for future enhanced oil recovery (EOR) development plan aiming for 70% recovery. This paper describes how a gas-based EOR development plan following the IOR plan was built, in an integrated manner, addressing the gaps and risks from core scale to field scale.
The integrated development plan consists of (a) review of past gas injection pilots, (b) injectant screening based on experimental results, (c) injection scheme selection to maximize the recovery, (d) configuration of the EOR pattern, (e) EOR application timing and rate optimization considering interaction with current development plan, and (f) investigation of surface facility requirements for EOR development.
A sector model study was done, using inputs from the SCAL and PVT experiments, for the screening ((b) and (c)) using the past pilot review (a). Learnings from the sector model simulation is deployed to the full field EOR application by dividing the field on the basis of maturity to water flood and historical development footprint, respecting the simplicity in EOR application without jeopardizing the ongoing production. Through simulation exercises, an integrated EOR plan was built ((d) and (e)). The proposed EOR plan efficiency is evaluated through full-field reservoir simulations, which takes practical drilling plan, well completion types and surface facilities constraints.
The simulation results demonstrated that the proposed plan (a) can recover oil without bypassing remaining oil, (b) can achieves 70% recovery based on selected gas, (c) is vigorous in terms of well count and well-head tower, and (d) utilizes the available surface facilities resources at maximum. The methodology used to design and evaluate the EOR development plan is applicable to other similar fields.
ESD Integrity Management - An Innovation in ESD Proof Testing
Authors: Chitnis Abhijit 
Published: November 2016

Abstract
IEC 61511 requires periodic proof testing of SIFs to demonstrate the correct operation of the loop elements based on Safety Instrumented Function (SIF) design criteria to maintain Safety Integrity Level (SIL) ratings. Proof test serves three primary purposes within the safety lifecycle:
To catch and overcome the failures in the system. To validate SIF integrity and reliability To record and classify failures in a consistent manner to support future analysis.
Challenges with implementing a new or modified approach to testing of Safety Instrumented System (SIS) instruments include issues such as education of participants, integrating the new proof testing procedures with the current maintenance plans and schedule, and documenting failures identified outside of testing. It is critical to create an implementation plan that deals with these challenges ahead of pushing SIS proof testing to facilities. This paper will:
Identify methods to achieve maximum % proof test coverage Proper planning and scheduling Review guiding principles upon which proof tests be developed.
Innovation - The Road Ahead
Authors: Siddiq Shafnas , Kindi Asmaa Al , Yahmadi Amal Salem , Rebello Sylvester , Rayssi Afra Al , Mallo Joshua Frial 
Published: November 2016

Abstract
Innovation in extremely simple words can be described as the deviation from the normal. But sometimes in our everyday efficiency driven work environment we are unable to devote enough time or attention to challenges that need creative thinking and innovative solutions. Another roadblock towards this deviation is connecting the talent which is sometime missing due to distance, environment and silo ecosystem. Organizations driven towards innovation try to overcome these roadblocks by approaching innovation in a structured manner and develop robust collaborative ecosystems supported by processes and technology.
This paper elaborates upon a combination of process and technology that can be deployed in organizations to use collective experiential knowledge to transform theoretical concepts into reality to have a positive business impact. In GASCO we use two specific approaches to drive innovation: Knowledge Café and Ideas Oasis.
Knowledge Café is a brainstorming approach that brings together group of experienced employees with a common understanding of specific challenge to have an open and creative conversation and arrive at solutions to resolve the identified challenge. The knowledge café sessions are divided in two parts, the first part is a quick overview of creativity that will set the momentum for the team, followed by tackling the actual challenge. The way it is structured, allows the participants to not only get an understanding of the subject, but also a process that will be followed in their regular work to think out of the box to tackle their challenges.
Ideas Oasis is GASCO's online ideation system that helps to capture ideas from employees and turn them into business value. It helps us to manage the process from idea creation, evaluation, approval, to implementation and reward.
Finite Element Analysis of the Installation Process of a Corrosion Protective Kevlar Reinforced Liner
Authors: Barsoum I. , Dymock J. , Walters R. , Seibi A. 
Published: November 2016

Abstract
Internal corrosion in pipelines is a persistent problem in the oil and gas industry. To the conventional rehabilitation techniques used to stop corrosion losses and prolong the life of the pipeline uses an internal lining system to isolate the corrosive medium from the host pipe's inner surface. To overcome many of the shortcomings of the conventional lining technologies, recently Kevlar reinforced flexible polymer composite liner has been developed. The installation of this flexible liner takes place in several stages and it is of interest to understand the mechanisms behind the installation process, and more specifically determine the forces and stresses at each stage of the installation process. Hence, the objective of the current study is to build a non-linear finite element model to simulate the full installation process of this new liner. The FEA model is further validated with physical tests, making it a reliable tool for simulating the entire installation process of this liner in an arbitrary pipeline network.
Reducing the Miscibility Pressure in Gas Injection Oil Recovery Processes
Authors: Rommerskirchen Renke , Nijssen Patrick , Bilgili Harun , Sottmann Thomas 
Published: November 2016

Abstract
In gas flooding EOR applications the injection pressure plays a significant role. It has to be higher than the minimum miscibility pressure (MMP) for a fully miscible flood to obtain the highest oil recovery, since the swelling, and consequently the efficiency of a flood, strongly depends on the miscibility of the residual oil and the recovery fluid. Poor miscibility leads to poor recovery. On the other hand the injection pressure must not be higher than the reservoir fracture pressure to avoid the creation of high thief zones in the formation. The addition of proper additives to the injection gas can reduce the MMP significantly.
Using a pressure resistant sapphire cell firstly the solubility of different additives in the gas at common reservoir conditions was determined. The compatibility of the additives with CO2 is needed to be ascertained first in order to identify compounds that enable an easy co-injection of the additive within the flow of the CO2. Then the miscibility behavior of the gas and a model oil was studied and the change of the miscibility pressure in the presence of chosen additives was investigated. Phase behavior studies at typical reservoir pressures and temperatures show the miscibility behavior of the fluids and the effect of the different additives on the mutual miscibility.
It was proven that the minimum miscibility pressure can be lowered significantly by the choice of an appropriate additive. Through determination of phase diagrams it is shown how the miscibility gap between crude oil and CO2 can be decreased, thereby going from immiscible or multi-contact miscible to fully miscible conditions. Adjusting the MMP broadens the pressure range of high sweep efficiency that is limited by the formation fracture pressure as the upper and the MMP as the lower limit. Thus, conditions can be created at which the reservoir pressure leads to fully miscible floods.
Using an appropriate additive can lead to an improvement of the miscibility behavior at given reservoir conditions and make it more favorable for a CO2 EOR process. A former near-miscible or even immiscible application can become a miscible flood. By this the sweep efficiency is maximized and the recovery rate is highest. The parameters that define an economic reasonable gas flooding application now comprise a larger number of reservoirs due to the improved miscibility of crude oil and injection gas.
Successful Real-Time Modeling of Wellbore Hydraulics Using Rheology Obtained According to API Recommended Practice 13D
Authors: Sindi W. , Prohaska-Marchried M. , Thonhauser G. 
Published: November 2016

Abstract
A deterministic method for standpipe pressure calculation in real-time using rig sensor data is presented. The main achievement is the development of a method for modeling wellbore hydraulics with satisfactory accuracy, despite lack and inaccuracy of information about the drillstring components. Exclusion of calibration makes the model more robust and lets the operator know the actual state of the model, at all times.
The methodology is based on dynamic geometrical representation of the wellbore-drillstring system, which is used to calculate wellbore hydraulics, utilizing analytical formulae, including the rheological models Power Law, Bingham Plastic and Herschel-Bulkley, as formulated in the API Recommended Practice 13D. The mud rheology is measured to this standard, i.e. measurements are taken at atmospheric conditions and temperature and pressure effects during drilling operations are neglected. The model accounts for changes in the pump rate and axial movement of the drillstring by means of real-time sensor data, including flowrate as well as bit and hole depth MD.
To validate the model, it was tested on 500 hours of recorded rig sensor data pertaining to drilling of the intermediate or production section of 4 wells using water based mud, and one deep-water HPHT well using synthetic based mud.
It was found that standpipe pressures are predicted with good accuracy for conventional drilling operations, when using water based mud, for both vertical and horizontal wellbores. The deviation between measured and predicted values was in the range of 0-10 bars. Short-term trends for measurements and predictions correlated very well. Further, it was observed that a single measurement of mud properties at the beginning of drilling operations enables sufficiently accurate modeling, even for several subsequent days of operation.
Modeling of the standpipe pressure of the HPHT well was found inaccurate, but modeled and measured data shared the same trend. Consequently, the mud shear stress increase due to downhole temperature and pressure conditions must be accounted for when modeling HPHT wells.
It is concluded that for drilling with water-based muds, the approach yields good results, despite incomplete information regarding the mudmotor and drillpipe tooljoints, and ignoring the temperature and pressure effects on mud properties.
Successful realization of real-time modeling of wellbore hydraulics is achieved through implementation of classical rheology models in an algorithm that understands drilling operations from rig sensor data, for water-based muds, without calibration. Workarounds concerning lack of data for tooljoints and the mudmotor are discussed and their corresponding errors are addressed. Beside the standpipe pressure, byproducts such as ECD, annular cutting velocities and flow regimes along the wellbore are determined in real-time.
A Comparative Study on the Performance of Acid Systems for High Temperature Matrix Stimulation
Authors: Ameri A. , Nick H. M. , Ilangovan N. , Peksa A. 
Published: November 2016

Abstract
This study presents a comparative analysis on the performance of acid fluid systems, which are commonly used for high-temperature (&gt;150°C) carbonate matrix stimulations. The comparison is based upon the key factors including ease of implementation, corrosion and operational costs, and performance assessment in terms of improving well deliverability. Moreover, core and field scale numerical simulations are performed to examine the rock matrix acidizing behavior under different reservoir conditions. The main variables are acid types, temperature, and injection rate. Results underline the conditions under which optimal stimulation concerning permeability and length of treatment is attainable.
According to results, a stand-alone stimulating fluid of glutamic acid diacetic acid (GLDA) shows the lowest corrosion rate followed by methanesulfonic acid (MSA) and hydroxyethyl ethylenediamine triacetic acid (HEDTA) under high temperature conditions. In the absence of corrosion inhibitor, GLDA gives the lowest results in terms of corrosion for 22Cr and 13Cr steels. Moreover, acid response data revealed that GLDA has the lowest optimum injection rate when compared to other acids considered in this study. Our simulation results show that the penetration depth (acid front) of acid is highly affected by the radial flow characteristics in field scale simulations, as the penetration depth is not linearly correlated to the volume of acid injected.