bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Application of Ultra-Lightweight Epoxy Resin-Cement Slurry Mixture Achieved Zonal Isolation Objectives and Secured Well Integrity: Case History From Offshore Gulf of Suez
Authors: Bhaisora Devesh , Aly Ahmed , Morsy Ahmed , Shamma Hesham , El Nashar Radi , El-Sayed Abdel Karim Salah Eldin 
Published: December 2015

Abstract
While drilling an offshore well in the Gulf of Suez (GoS), Egypt, an operator experienced severe losses of approximately 14,500 bbl of costly oil-based mud (OBM) during the drilling of a 12 1/4-in. hole section through depleted zones. It became obvious that zonal isolation objectives would not be achieved unless equivalent circulating density (ECD) was significantly reduced during cementing to help minimize and control downhole losses.
Therefore, a special design of ultralightweight cement slurry combined with epoxy resin was prepared. The goal was to help reduce downhole losses during cementing while enhancing mechanical properties and achieving higher compressive strength of the set cement sheath as per well integrity requirements. This would help prevent formation stress and be helpful during future well construction operations. Epoxy resins are primarily used as secondary barriers to the primary cement sheath, curing tight casing leaks, squeezes, and during well abandonment. Generally literature on resin discusses its resilient mechanical properties, highlighting that the Poisson's ratio of epoxy resin can be closer to that of rubber, while cement is closer to that of glass.
It was observed that mixing resin with cement enhances other mechanical properties of cement in addition to enhancing compressive strength. A 9-lbm/gal resin-cement slurry mixture was designed for the discussed treatment, combining 90% cement and 10% epoxy resin. The combined mixture provided all of the necessary properties of the desired cement slurry. The cement treatment was performed as designed and met all zonal isolation objectives.
This cement-resin mixture can become a new solution within the industry, replacing conventional cement in many crucial primary cementing applications, particularly replacing ultralightweight high-compressive-strength slurries. This paper highlights the necessary laboratory testing, field execution procedures, and treatment evaluation methods so that this technology can be a key resource for such operations in the future.
An Innovative Approach for Tubing Integrity Monitoring With the Application of Electromagnetic Tool and Caliper Tool in Tandem
Authors: Norintan Farina Haziq , Hafiz Azzad , Safwan Aliff , Norfasya Norfasya , Xiong Choi Yee , Zawawi Ahmad , Yusmanizeil M. , Aisyah Siti , Idham M. , Wahyudeen M. 
Published: December 2015

Abstract
Caliper survey is well known for its accurate measurement of inner casing and tubing since the introduction to the market few years ago. From the survey, most pipe integrity issues with failure size as small as pitting can be measured to a better understanding on the tubing conditions. Most of the failures on pipe developed over time and small pitting more than often turn into damaging large hole as time goes by. Thus, caliper survey provides an ideal solution for monitoring the pipe integrity condition.
Not until the recent innovation of a new electromagnetic tool altered the perspective on monitoring the pipe integrity condition. By combining with caliper tool, it improves the pipe integrity survey by identifying the location of weaknesses; in specific the exact point of metal loss, as well as to measure the thickness of the tubing. Applying the remote eddy current concept, the magnetic wave will travel from the wave generator, along the outside of the casing before passing back through the 12 sensors mounted on the inside of the tool's bowsprings. The casing thickness affects the arrival time, phase and amplitude of the returning signal and this info will be analyzed with the improved 3D visualization software and statistical software.
Three (3) wells; A, B and C were completed during 1990's. The wells have high CO2 content at 9–15%. Surface facilities in the field have limitation in handling high CO2 fluid, thus these wells were producing intermittently from 1996–2010. An upgrading of surface facilities were undertook from year 2012–2014 to maximize the technical potential of the wells in the field. Workover job was agreed upon the upgrading but intervention team has another idea in looking into the matters. A logging survey was proposed consists of caliper, electromagnetic and pressure gauge to evaluate the conditions of the tubing integrity. The logging involved the entire tool associated in real time and tandem, the first time ever done in this region. The results from the survey showed differences of corrosion percentage between caliper data only and combination of caliper and electromagnetic tool. Combining these techniques of survey in tandem gives a more details corrosions percentage and thickness compared to caliper only. It also minimized the operation logging time and well downtime. In conclusion, it was found that the current tubing thicknesses of these wells are within the allowable corrosions rate, consequently workover campaign was dropped and roughly around USD 30 Million had been saved.
The comprehensive strategy on running these surveys in tandem provided in this paper can be used as guidance for an innovative approach in corrosion monitoring.
Pilot Trial of HR-PCP Technology for Heavy Oil Reservoir in KOC
Authors: Mali Prasanna Vasant , Al-Jasmi Ahmad , Saleh Iskander , Al-Ajeel Fatemah , Mariam Zerai , Shah Jignesh , Al-Olaimy Saber 
Published: December 2015

Abstract
Exploitation of heavy oil fields is a challenging task in Kuwait Oil Company (KOC). Most of these fields require artificial lift to produce optimally. Reliability, operational ease, run-life and steady oil gain, are the key issues, for application of artificial lift, to produce heavy oil. It is our constant endeavor to seek value addition, with regard to these parameters. In view of this, pilot of ‘Hydraulically Regulated PCP’ (HR-PCP) technology, is implemented for heavy oil cold production.
Preliminary studies revealed that HR-PCP technology is designed to handle multi-phase flow conditions more efficiently, due to its unique design. Pilot trial is carried out for a representative heavy oil reservoir, having crude oil gravity of 14°API, with top of the perforation at 7819 feet. Objective of the pilot is to evaluate performance of HR-PCP technology, with regard to the heavy oil cold production. Study is based on actual field implementation and does not include any lab studies.
The paper, essentially, encompasses various aspects of the pilot such as pilot methodology, technology evaluation, candidate well selection and HR-PCP design as well as details regarding pilot implementation and pilot study results. During the pilot period, relevant pump and well parameters are constantly monitored, with an aim to optimize pump performance.
It is concluded from the pilot results that implementation of HR-PCP technology, for this heavy oil reservoir, is proven to be successful in terms of achieving steady oil gain and sustained run-life. Maximum oil rate of 567 b/d and peak MTBR of over 400 days, are achieved during the pilot period. Pilot studies have also prompted us to install HR-PCP technology for other similar wells.
Thus, HR-PCP technology emerges, as a viable artificial lift mode for our heavy oil production strategic plan. Results amply demonstrate that the technology can also be applied for other heavy oil reservoirs of similar nature.
A Study of the Applicability of Bourgoyne & Young ROP Model and Fitting Reliability through Regression
Authors: Kutas D. T. , Nascimento A. , Elmgerbi A. M. , Roohi A. , Prohaska M. , Thonhauser G. , Mathias M. H. 
Published: December 2015

Abstract
Pre-salt layers has long-term exploration and production possibilities, however the properties of such layers are highly challenging for exploration (i.e. these carbonate layers are highly abrasive, located deeper than 5000 m, have generally low permeability) and production (i.e. pre-salt layers are located in harsh oceanic conditions, hundreds of km offshore). These conditions mean increased exploration technological and economic difficulties. One of the partial solutions to decrease costs is to reduce the drilling operations time. Rate of penetration (ROP) has a significant effect on the overall drilling time, driving ROP modeling and optimization to be a viable solution for reducing drilling operations time in such environment. Several mathematical ROP models were developed in the last five decades in the petroleum industry, departing from rather simple but less reliable R-W-N (drilling-rate, weight-on-bit and rotary-speed) equations until the arrival to a comprehensive and complex approach: Bourgoyne and Young ROP Model (BYM) which was first published in 1974.
The paper explains the equation, how it is applied in terms of ROP modeling, identifies the main drilling parameters driving each sub-functions, and introduces how they were developed. The paper base itself on the sub-functions of the equation, explains the normalization factors which have significant influence on the model, and also introduces simulations which aim to understand the approach by applying the equation in a pre-salt layer case study. Knowing that, the original publication was introduced in 1974, this paper also aims to identify rooms for improvement and/or alternate the sub-functions to match actual field data better than with the originally given drillability coefficient recommended boundaries stated in the first publication. This is accomplished through a real-world practical application of this ROP model in a pre-salt layer. The paper also assesses the limitation in terms of the applicability of this complex model for ROP analysis and optimization in such carbonate layers.
Managing an Effective Centralized Control Room for Brown Field Projects in Gas Plant
Authors: Dey Nilangshu 
Published: December 2015

Abstract
Natural Gas liquid (NGL) Plants in Qatar have undergone major operational transformation during the last decade. The large step change in operational strategy and efficiency has occurred due to automation evolution taken place in monitoring, control and protection technology of all Gas plants of Qatar Petroleum.
The Paper will focus how the major upgrades of the Plant control and safety systems done thru various brown field projects which have introduced new centralized operational interfaces resulting multiple operating systems in the same control room and ultimately the final solution done in integrating all such operating systems to an ergonomic control room environment.
It highlights the various challenges faced while implementing such brown field projects at different stages within the existing control room environment. Few of such upgrade projects has also been highlighted which has created direct impact on operations in achieving various benefits.
Further the Paper highlights detail case studies on NGL-3 Plant where such brown field projects has made operational hindrance and subsequently major revamping projects were undertaken to integrate the various control systems into a single operating platform with ergonomic operators console and control room layout for 24 X 7 effective operation.
The Paper also provides the multifold operational benefits of rationalization of centralized control room environment thru integration of multiple satellite control systems and converting the operator interfaces to ergonomically designed Extended Operator Console for 24 X 7 efficient operation. It provides the various elements which has directly contributed towards the real operational benefits.
Structural Uncertainty and Inverse Characterization of Discrete Fracture Networks with Dynamic Data
Authors: Vargas-Murillo B. , Vargas-Guzmán J. A. 
Published: December 2015

Abstract
The realism of modeling well stimulation by hydraulic fracturing, in 3D reservoir grids, heavily depends on the match between the predicted multiple-scale discrete-fracture-network (DFN) and its flow properties, versus the monitored fractures at drilled rocks. Unfortunately, monitoring the hydraulic fracturing phenomena and connectivity of DFNs at multiple scales is highly uncertain. Although fracture orientation and location are measurable at wellbores, and microseismic has contributed to characterize hydraulic fracture geometry; the subseismic connectivity of hydraulic and natural fractures with sweet-spot rock-bodies at larger distances demands advanced integration of preexisting structural features into numerical models. Therefore, modern fracture optimization demands the use of 3D stochastic reservoir models. Additionally, mismatches between the reality and the model are incidentally observed by comparing bottomhole pressure and multiphase flowrate response in flow models versus downhole monitored data. Attempting to recreate the fracturing process requires coupling hydraulic injection, fracturing geomechanics, proppant transport, and flow under preexisting structural uncertainty; at multiple scales. Although tools for modeling such a complex workflow exist, results do not automatically match microseismic or other advanced observations, due to preexisting structural uncertainty in the model, and/or limitations of the tools themselves.
In this paper, the importance of multiple-scale structural-heterogeneity is emphasized, and the use of "practical" inverse problem solutions of DFN models is suggested for its characterization. The proposed inverse approach is to modify structural object positions, attitudes, and geometries, instead of upscaled flow properties. An industrial scale example of such approach, where the size of pseudo-compartments is controlled by subseismic sealing faults, is recalled. Errors in pressure response are correlated to fracture displacements along normal vectors. The use of streamline simulation to facilitate tomography of DFN intensity is evoked. The multistage fracking process is also proposed to be handled with the same approach, modifying the geomechanical fracture model to match monitored flow and proppant transport response. Finally, novelties for monitoring proppant transport during fracturing are also highlighted.
Design, Installation and Integrity Management Challenges of Bolted Connections for Offshore Brownfield Modification Projects
Authors: Nezamian A. , Iqbal K. , Nicolson R. 
Published: December 2015

Abstract
The integrity management, changes, repairs, upgrades and modification of offshore infrastructure to meet the functionality and operational availability requirements presents a constant and growing challenge for operators. A bolted connection arrangement can form a constructible and cost effective solution for the modification of existing platforms with minimum impact on platform operations. Historically, bolted connections have been avoided due to concerns about integrity management and degradation mechanism uncertainties and corrosion in particular. However, where structures are not in direct contact with sea spray, and given appropriate safety and integrity procedures, bolted connections can be used successfully on live production platforms to mitigate risks without the exposure to hot work.
The use of bolted connections covers a wide range of applications. This implies that the requirements for a bolted connection must be specified in relation to the given application and its criticality. As the requirements for fastener material, specification/design and installation are defined based on the given application, the present guideline does not provide specific requirements (minimum requirements) that can be used universally. In addition the installation procedure assurance, integrity management and corrosion protection of bolted connections require an appropriate degree of attention.
This paper gives an overview of the challenges and discusses various aspects of bolted connections related to brownfield modification of offshore structures. The discussion aims to represent potential risks to the integrity and the required mitigation actions and overall requirements for design, installation, maintenance, re assessment and repair to maintain the structural integrity of the bolted connection and attached structures. The paper also provides an overall view on the documentation and calibration/validation of the bolted connections required to ensure an adequate safety level is maintained by means of maintenance and inspection programs.
Designing of Successful Immiscible Water Alternating Gas (IWAG) Coreflood Experiment
Authors: Khanifar Ahmad , Raub Mohd Razib Abd , Tewari Raj Deo , Zain Zahidah M , Sedaralit M Faizal 
Published: December 2015

AbstractAverage recovery factor in offshore field under discussion is relatively moderate due to wider well spacing and poor sweeping efficiency thus leaving significant volume of oil behind in the reservoir. Timely application of EOR is therefore necessary to enhance the recovery factor to a reasonable level. Among the various EOR processes and techniques of EOR screened, studies found immiscible water-alternating gas (IWAG) injection as the most suitable and viable option for this Malaysian mature offshore oilfield. Realistic estimate of incremental oil by EOR is paramount as IWAG application involves high CAPEX and OPEX project. Therefore, representative is required to be generated in the laboratory for constructing a realistic reservoir simulation model to understand the three phase flow in porous media and support the IWAG process for full field implementation. Important parameters in this case are residual oil saturations in sequential injection of displacing fluids water and gas and trapping of gas, injection volumes and frequency of alteration. Therefore, IWAG core flooding experiments under reservoir conditions need to be performed, results quantified and parameters for hysteresis modeling established.This paper addresses the challenges and strategies of IWAG core flooding experiment performed under reservoir conditions using representative composite native cores, live reservoir oil sample, field produced gas sample and synthetic formation brine water. The laboratory injection rates are considered equivalent to the field fluid advance velocity like in any standard displacement steps. Also, gravity stable injection mode is considered to achieve the best IWAG displacement performance. These challenges and strategies are drawn from lessons learned during accomplishment from earlier IWAG core flooding experiments. The IWAG core flooding experiments were performed on composite field core samples, arranged according to Langaas method, using current field production gas with 60 mole % CO2. The composite reservoir core samples were initially saturated with live oil and irreducible formation water and then flooded with formation water and seawater to residual oil saturation at reservoir conditions. Following, waterflooding, a number of water and gas cycle slugs were injected. The displacements were conducted at pressures well below the estimated minimum miscibility pressure during these experiments. Laboratory studies and numerical simulation study conducted on the applicability of immiscible WAG injection using high CO2 content produced gas indicated that 7.0 % additional oil recovery over waterflooding period can be recovered.
Improving Brownfield Project Performance
Authors: Visser Folkert , Burger Mark , Laws Simon 
Published: December 2015

Abstract

Brownfield project performance
When a new facility starts up, a new brownfield site is created. Through technology improvements we are able to get more production out of our existing assets and getting access to new frontiers is increasingly complex. These factors raise the importance of doing brownfield projects well.
But, the schedule and cost slippage that is often found in capital projects is significantly worse for brownfield projects.

Typical issues in brownfield projects
Project cost growth and schedule slippage often occurs in the early phases of the development. Project and asset teams may lock themselves into pre-determined solutions for brownfield projects without spending sufficient time on the front end loading, driven by an attitude of already knowing what needs to get done. Surprises appear during execution because of a lack of understanding of the facilities, such as its current condition, the process constraints and the restrictions to execute the projected work. Estimates and schedules can grow because they were based on analogues or factors, which turn out to be unreliable due to the unique nature of each brownfield project.

Best practices
Due to their many interfaces and complexity, brownfield projects require discipline: to spend time to truly understand the asset, to get sufficient detail early to develop a realistic estimate and schedule, to appoint experienced operators to support the project team at the early stage of the project, to allocate sufficient funds to perform high quality front end loading and to plan the work in detail once in the field. New technologies can improve brownfield projects outcomes, e.g. laser scanning, 4D execution planning, novel inspection techniques and advanced data management.
This paper will explore what best practices reduce complexity and improve performance. Through proper framing, dependencies with other work on the asset can be minimized and this reduces the risk of delays. Transferring work from the live construction site to an offsite fabricator will lead to less safety exposure, better quality and a more predictable schedule. Performing trial fits prior to shipment further reduces the risk of execution inefficiencies.

Recognition
The recognition of the inherent complexity and challenges associated with brownfield projects at all levels of the company, will lead to better consistency in execution of this projects. Experience with executing brownfield projects and with the particular facility is a pre-requisite. Being successful at extending the life of our existing assets will then bring large rewards.