bluuebunny/crossref_metadata_2025_split huggingface dataset:
Advancing the Understanding of Openhole MultiStage Completion Systems in Khazzan—Hydraulic Fracturing Execution and Analysis
Authors: Ishteiwy O. A. , Casero A. , Al-Shueili A. , Turk G. , Roy A. , Al Manji A. , Dawson W. , White D. , Kurniadi S. D. 
Published: November 2017

Abstract
The Khazzan development in the Sultanate of Oman operated by BP includes a multi-layered gas reservoir with stresses impacted by tectonic activity which has led to numerous challenges around multi-stage hydraulic fracturing of horizontal wells within the field. These wells were primarily focused on cased-cemented horizontal sections through the reservoir but a decision was taken in 2014 to trial openhole multistage (OHMS) completion systems to understand their applicability in this field and the potential advantages such systems could bring with respect to the challenges seen in the cased-cemented systems. Two such systems have been run to date in the Khazzan development. Significant consideration has been given during the planning phase to follow a systematic process of implementation to deliver an effective learning curve with clear understanding of the impact of design and execution changes between wells.
This paper will describe the details, including completion and fracturing design, fracturing execution and surveillance, and post-fracturing clean up and production, of the second OHMS well in the Khazzan development. The second well has built on the success of the initial trial and the well has been designed to demonstrate the repeatability and the reliability of this completion type in Khazzan. It was also tailored to further the understanding of some key unknown or uncertain elements of the fracturing treatments following the analysis and interpretation of the first OHMS completion.
Specific focus areas that will be addressed in this paper include the use of a hydraulically activated toe fracturing sleeve, the effect of a reduction of mechanical packer spacing on fracture staging performance and efficiency, ball drop efficiency, and overall fracture execution efficiency improvements.
A comparison of the system's performance across different reservoir quality will be examined, with the second system having been deliberately deployed in relatively low reservoir quality rock. The impact of various degrees of over-flush and under-flush on the individual fracture stage production performance will be reviewed. This is an important consideration for more conventional Middle East reservoirs and is often perceived to be a barrier to the implementation of the highly efficient systems currently deployed by North America.
Engineering Documents from Jurassic Era to Avant-Garde
Authors: Tayfor Hussam , Kumar Anish 
Published: November 2017

Abstract
Documents quality and documents control was of less significance in the past. This has been mainly due to limited drawings tools available in the industry for the data management and due to considerably small scale of technical requirements for data filing, restoration and archiving.
Majority of engineering data and drawings in the 70s’ were available as hardcopy versions of various sizes & types (ammonia print, tracing papers, hand written data sheet …etc.).
Filing and document control was solely maintained in hardcopy logbooks and registers. Introduction of computers based application helped to some extent in generating index for documents which in-turn enhanced filing administration and document controlling.
The uprising in the industrial technology took place in the 21st century has come with major challenges and compelled emergent of parallel technologies for the database management and control systems.
The above scenario was experienced also to Gasco Company throughout the years of its rapidly progressive development.
With the idea in mind; plant data shall always be maintained to reveal the 'As-Built' status, Gasco has emerged vastly on the deployment of the latest integrated technology that can deliver the ultimate intelligent database management platform for sustainable and traceable as-built database and integration at the corporate level.
History Matching of Integrated Reservoir Simulation Model for Green Field Offshore Abu Dhabi
Authors: Semenov A. , Altaf B. , Allouti A. , Bu-Hindi H. , Ibrahim L. 
Published: November 2017

Abstract
Integrated reservoir simulation model (IRSM) is a common working tool in multidisciplinary teams nowadays. Usually such models constructed and used before field production startup, on the pre-project stage. But authors are commonly missing part about how good is the prediction ability of the model after first production and pressure data acquired? History matching, calibration of all parts of integrated model (reservoir, well, surface pipelines) requires constant efforts of multidisciplinary team or even building new model from scratch. In the scope of the paper the preparation of dynamic integrated reservoir simulation model and calibration based on 2 years of Phase 1 field production is covered.
Commercially available reservoir simulator with fully coupled network infrastructure was used for modeling purposes. Multi-reservoir static model grid was linked with networks (oil production, gas and water injection). Real time data from well downhole gauges (including smart wells) and MPFMs were used for reservoir models HM. Additional data from surface gauges and export meter were used to calibrate pressure drop in wellbore and surface pipelines.
Initially created IRSM was not able without HM stage and calibration to accurately predict the reservoir performance and pressure in the surface production system. Exceeding complexity of the model was decreasing the accuracy of the forecast even more. Only after history matching step for all wells using daily pressure/rate data and implementation of real pipeline layouts, the model was used for different purposes such as well placement and business planning. Highly efficient prediction tool was constructed in the scope of the study.
Liquid Cement Premix System for Rigless P&A
Authors: Thom Douglas 
Published: November 2017

Abstract
Plug and Abandonment (P&A) operations are integral to the decommissioning phase of an offshore installation. The most critical aspect of the P&A is the cementing operations, in which cement slurry is used as barriers to isolate potential flow zones and verify abandonment. Typically, this is conducted at the rig site where bulk cement, water and specialized additives are mixed and pumped downhole. While the practice of cementing is well established, it can be challenging to conduct such operations efficiently in P&A environments such as dealing with ageing equipment or where a rigless solution has been adopted.
This paper will highlight the use of a Liquid Cement Premix (LCP) system on a rigless P&A project in the North Sea in which three wells required permanently abandonment. The LCP system was used as an alternative to conventional cementing operations due to its benefits in equipment reduction and more efficient logistical solution. Due to the importance of the LCP operations, significant measures were required in order to ensure the quality control of the LCP. This paper discusses these measures adopted in the onshore, offshore and laboratory phases of execution.
It was found that LCP can provide a superior alternative to conventional cementing operations as the product behaved in a reliable and consistent manner. All three wells successfully abandoned with no nonproductive time (NPT) attributed to the LCP operations.
The Value of Rate, Temperature and Pressure Surveillance in Steam Assisted Gravity Drainage SAGD Process
Authors: Shaker Wisam , Chen Zhangxing , Walker Greg 
Published: November 2017

Abstract
Steam Assisted Gravity Drainage (SAGD) is used in West Canadian Sedimentary Basin (WCSB) for heavy oil recovery and numerical simulation is quantitative tool, which can be used to evaluate the SAGD performance and test developments options. This paper starts with the assumption that a single model is unlikely to be correct, and cannot represent the range in the outcomes due to the reservoir complexity and fluid heterogeneity. An alternative is to generate a number of models through an assisted history matching (AHM) process, with the intent of providing realistic estimates of the remaining uncertainty and quantifiable options to reduce the uncertainty. For a new piece of surveillance to add value, our working hypothesis is that the new surveillance should not be correlated with existing surveillance to avoid redundancy, and that the reduction in the range of acceptable models provides a way of quantifying the value. For our SAGD study, we are evaluating if temperature and pressure surveillance in observation wells has value, and how they should be included in the objective function.
A synthetic two-dimensional SAGD model was used in the simulation, with a known truth case against which we can test the efficiency of different types of surveillance to recover the true reservoir performance. Three observation wells are distributed through the model with five stations for temperature and pressure measurements. To test the value of the temperature measurements and observer well, a blind searching algorithm was use initially to avoid introducing a search bias that could distort the correlation. Rate, pressure and, temperature misfits were calculated for each experiment. The model with less than 5% rate misfit were filtered and run for several years in prediction with the same depletion plan. The improvement in the lower confidence bound for the value of the field used as the benefit of the surveillance.
A second test was to use an exploitative search technique on a simple arithmetic objective function. As expected, the global minimum did not represent the truth case performance, though the truth case was in the intersection of the surveillance constraints of matching pressure, rate and temperature within noise. The correlation between temperature and pressure surveillance show some correlation, such that there is some redundancy, yet the analysis of the models resulting from both parts showed that pressure and temperature surveillance have reduced the uncertainty in the future outcomes by 84% in cumulative oil production and 82% in the NPV.
The proposed workflow used here will allow quantifying the potential of adding a new surveillance to the field and/or specifying the number and locations of the required observation wells which properly capture the steam chamber development and pressure propagation throughout SAGD reservoir.
Real-Time Resistivity Monitoring Tool for In-Situ Foam Front Tracking
Authors: Haroun Mohamed , Mohammed Abdul Moqtadir , Somra Bharat , Punjabi Soham , Temitope Ajayi , Yim Youngsun , Anastasiou Stavroula , Baker Jassim Abu , Haoge Liu , Kobaisi Mohammed Al , Karakas Metin , Aminzadeh Fred , Corova Francisco 
Published: November 2017

Abstract
Surfactant Foam assisted CO2 EOR, though getting traction for its environomic mobility control potential, faces numerous challenges for deployment in HPHTHS heterogeneous carbonate reservoirs. Amongst the major challenges, the first is the lack of a surfactant formulation compatible with our carbonate reservoirs and the second is the absence of a foam and CO2 front monitoring tool either at laboratory or field scale.
In this study, a novel monitoring technique has been developed to track quality of the foam while core-flooding. This is essential to capture the onset formation, development rate and break-through of the said foam across varying length of core-plugs. This has been previously conducted in lab-scale by virtue of pressure response with or without expensive imaging methods. This tool complements the conventional method of studying pressure response with resistance measurements across the core allowing tracking of the foam generation and propagation. Various preconditioning smart brines (SB) were alternatively injected with the non-ionic surfactant APG, co-injected with gas, to generate foam in-situ in carbonate reservoir samples. In addition, we briefly discuss a new idea involving resistivity and pressure measurements for the optimization of foam (and CO2 foam) injection into porous media
The foam generation, stability and breakthrough were studied as a function of salinity, ion composition and injected pore volumes of the various brines and surfactant. Core-plugs of 2 different rock types were flooded with 4 variations of smart brines at a constant flow rate. The tested formulations were ramped up from 2 to 8 pore volumes. The response of the ΔP/PV integrated with the Δρ/PV curves were analysed to detect foam generation and breakthrough. This allowed an immediate characterization of the foam performance providing capability of tracking the foam formation/dissipation across the length of the core-plugs, essential for compatible successful foam formulation.
This novel method allowed for instantaneous resistance observations in lab-scale along with the pressure response. The performance of the monitoring technique provided a new dimension in understanding foam flooding. This was integrated to provide comprehensive analysis of the formulated foam. Our innovative method provides the capability of quicker screening to successfully generate foam in-situ in high salinity, hardness and heterogenic environment.
Monitoring of Greenhouse Gas Emissions From Space in the Middle East
Authors: Gauthier Jean-Francois , Germain Stephane 
Published: November 2017

Abstract
In June 2016, GHGSat launched the world's first satellite capable of measuring greenhouse gas emissions from targeted industrial facilities around the world. We offer a single solution to measure emission rates of carbon dioxide and methane from selected targets with greater precision and lower cost than ground-based alternatives, across a wide range of industries. GHGSat is deriving the emission rates of these sources from 12 × 12 km maps of the atmospheric column densities of carbon dioxide and methane produced using its patented sensor at a spatial resolution better than 50 m. Satellite mass is less than 15 kg. Our solution provides industrial site operators and government regulators with the information they need to understand and manage their greenhouse gas emissions better and ultimately to reduce them more economically. We will describe the system, including the sensor and satellite specifications. We will also describe our products and services, show how they apply to the oil and gas industry in the Middle East and provide examples of various levels of imagery taken from the region with our satellite.
Successful Field Application of Bulk Water Removal Debottlenecks Declining Songkhla Marginal Offshore Fields, Extending Economic Life
Authors: De La Sota Manuel 
Published: November 2017

Abstract
High watercuts (WC) and bottlenecked processing facilities can become killers for offshore marginal and declining fields. Bulk water removal has proven to be a solid quickly implemented solution for these production scenarios. This paper presents the challenges and lessons learned by Compañía Española de Petróleos, S.A. (CEPSA) fully owned subsidiary, CEC International Ltd. (CEC), in their successful field application of this principle to extend the economic lives of two declining and watered out Songkhla offshore fields located in Block G5/43 of the Gulf of Thailand.
In 2015, a redevelopment drilling campaign was undertaken in two fields of Block G5/43 in order to increase the oil production and accelerate reserves recovery. At that time, a need to increase the fluid handling capacity was identified to accompany the new production wells. After an intensive market exploration, and a positive field trial, the design selected consisted on bulk water removal by means of high efficiency hydrocyclones upstream the bottlenecked three-phase separator. The application of this design, together with a full revamping of the existing production facilities, commissioned in 2016, made CEPSA-CEC a pioneer in the use of this principle in South East Asia (SEA) and allowed substantial oil production increases with minimum incremental operating cost, extending economic life of the fields.
The application of bulk water removal can become a robust opportunity for those fields that are now experiencing a sharp production decline, with high WCs, and bottlenecked production facilities. The CEPSA-CEC case can serve as a model for expanding this technology and enhancing production from aging fields. This article presents project details and lessons learned hoping that they can serve to other Oil and Gas (O&G) companies facing similar limitations.
Deterministic and Stochastic Seismic Inversion, a Comparison Study Applied to Capture Major Heterogeneities and its Associated Uncertainties during Early Characterization Stage in Upper Jurassic Reservoirs in the UAE
Authors: Aamir Muhammad , Figuera Luis Gerardo , Hosani Khaled Al , Singh Maniesh , Ahmad Mula Nur , Solaiman Tarek , Qallabi Salah Al , Araque Arcides , Dike Nnamdi , Krissat Widad , El-Mawla Walid , Aly Omar , Elsayed Raghad , Mukherjee Anubrati , Nyein Glenn , Havelia Khushboo , Nafie Tarek 
Published: November 2017

Abstract
The studied Fields cover about 1900 sq km covering fourteen wells in Abu Dhabi, UAE. It was discovered in 1962 and developed by Abu Dhabi Petroleum Company. The objective of the current study is to illustrate the comparison between prestack stochastic & prestack deterministic seismic inversion results to better understand vertical and lateral heterogeneities of upper Jurassic reservoirs and their impact on property distribution during static modelling and further into dynamic model construction.
Upgrade Rig Moving System for Existing Land Rigs
Authors: Elrefai Mahmoud M. , Abd Elnaby Osama 
Published: November 2017

Abstract
In the last 10 years and due to high demand for new designs of drilling rigs to meet recent requirements for drilling challenges, NDC came up with new innovative solutions to convert existing old conventional moving rigs to new fast move rigs and/or other specific moving features such as drilling cluster wells. Conventional rigs' designs focused about drilling operation performance with less considerations to the fast rig move However due to technology improvement as a response to the stringent safety protocols and industry’s increasing focus on operational safety and efficiency.
NDC upgraded two types of existing rigs as followed: Fully dismantled rig with conventional design in 1981 to fast moving rig with advanced drilling features.Normal move rigs design to Cluster walking rig with unusual drilling features to be the first type in middle east.
Challenges lies in our main goal to meet latest API design requirements (Drilling loads, wind loads, rig move conditions, ..etc) as rigs had been designed for different design criteria.
NDC engineers along with rig designers and rig builders apply years of experience to deliver optimal solutions based on material selection, service application and functioning criteria.
Pipeline Leakage Detection Using Fiber Optics Distributed Temperature Sensing DTS
Authors: Mishra A. , Al Gabani S. H. , Jumaa Al Hosany A. 
Published: November 2017

Abstract
With increasing public consciousness and concern for the environment, recent pipeline leak incidents across the globe have proved that the cost to a company can be far more than the downtime and clean up expenses. As more stringent statutory regulations are getting introduced, cost effective and reliable leak detection systems are in demand.
"In the past few years, innovative distributed temperature monitoring techniques using optical fibers have demonstrated to be an efficient way to detect and localize leakages along pipelines. These techniques use a concept similar to Optical Domain Reflectometry (OTDR) for the localization, whereas the temperature information is extracted from the analysis of the scattered light through Raman or Brillouin scattering processes. Raman-based systems were first proposed and used in practical applications, while the Brillouin-based technique has been introduced in the early nineties and offers longer distance ranges" [2].
The manuscript details the methodology adopted to monitor gas pipeline leakages using distributed fibre optics sensing techniques. DTS has been introduced to UAE pipelines by GASCO through their first ever installation in HRS (Habshan - Ruwais–Shuweihat) gas pipeline followed by HMT (HabshanMaqtaTawelah) Pipeline Projects.
Baseline Establishment for a Polymer Flood Pilot Test in an Unconsolidated Sandstone Reservoir in the South of the Sultanate of Oman
Authors: Al-Sulaimani Hanaa , Al-Rawahi Zainab , Quesada Conny Velazco , Al-Ghannami Mohammed , Frumau Mervin , Al-Hussaini Azza , Hemink Gijs , Nadeem Muhammed , Khattak Ali , Al-Hinai Ghalib , Al-Mahrooqi Majid , Al-Shidi Maitham , Syed Muhammad 
Published: November 2017

Abstract
Petroleum Development Oman (PDO) has commenced several Enhanced Oil Recovery (EOR) methods in the Sultanate of Oman to increase recovery from fields with challenging rock and fluid properties. Polymer flood is one of the mature EOR techniques that are currently operated in sandstone reservoirs in the South of Oman.
The reservoir under trial in this paper shares its OWC with another reservoir that has been developed through polymer flood. Although they both share similar fluids with viscosity of ~90cP, the reservoir under trial exhibits significant lower permeabilities, which poses a risk to injectivity. Furthermore, well completions with sand control have shown to be too detrimental to productivity which causes high sand production. This creates a challenge for the polymer flood from both the injectivity and sand control point of view. Thus, a pilot was designed with the following three objectives; test ability to sustain injectivity of polymer into the reservoir, monitor polymer efficiency, and evaluate operational impact on facilities due to sand production that is expected to increase with polymer flood.
The pilot was designed such that two patterns are drilled adjacent to each other where one will be used for the polymer flood and the other pattern serves as a backup in case the first pattern suffers from loss of injectivity or any unforeseen issues. The patterns are inverted five spots with an injector-producer spacing of 75m. The injectors are equipped with fiber optics for data acquisition and real time temperature and acoustic surveillance. The plan is to inject water until a baseline is established, which is then followed by polymer injection for up to one year.
Currently, the project is in the water injection phase where information and data are gathered such as injectivity, conformance, reservoir connectivity in addition to fluids production baseline establishment. This paper presents those findings from the water injection phase in addition to design aspects for the polymer phase.