bluuebunny/crossref_metadata_2025_split huggingface dataset:
Risk Mitigation for Further Development of a Mature Field through Multiple Parameter Sensitivity Study
Authors: Yamada Tatsuya , Yamamoto Kei , Alqubaisi Alyazia , Al Jasmi Sami , Uematsu Hiroshi , Kojima Keitaro , Shibasaki Toshiaki , Al-Jenaibi Faisal 
Published: November 2018

Abstract
Reservoir simulation is widely used for field development planning in many fields and the evaluation of uncertainty range in production forecast is indispensable to make decision for further investment. Reservoir simulation model consists of geological, petrophysical and reservoir engineering parameters for each cell and cell boundary. These reservoir model parameters are usually defined based on limited available data in consideration of their uncertainty range. Therefore, the identification of influential parameters and the reduction of uncertainty range for these parameters are key components to mitigate the prediction uncertainty.
An Upper Jurassic carbonate reservoir in Field A located in offshore Abu Dhabi has long production history for more than 30 years. Field A experienced several development schemes including natural depletion, crestal gas injection and crestal water injection. The current reservoir simulation model reasonably replicates historical performance on pressure, water cut evolution and GOR trend in field and well-by-well scales. On the other hand, we identified some reservoir model parameters have high uncertainty due to reservoir complexity and lack of reliable data.
In this study, we focused on the identification of influential parameters on production forecast and the reduction of parameter uncertainty range using an experimental design approach. More than 200 simulation cases were generated with different combination of selected parameters using Latin Hypercube Sampling method. In each case, we evaluated history matching quality in field scale and relationship between history matching quality and each parameter. We found some parameters have correlation with history matching quality independently from the other parameters settings. This means that the uncertain range of those parameters can be reduced to achieve an acceptable history match irrespective of the other parameters. Furthermore, the prediction uncertain range was analyzed using the selected cases showing reasonable history matching quality to investigate the relationship between cumulative oil production and each parameter. The results indicated some parameters have a stronger impact on production forecast and their uncertainty range need to be reduced by further data gathering or considering other mitigation plans. This study successfully demonstrated that the proposed multiple parameter sensitivity analysis by effective use of experimental design approach enables to reduce the parameter uncertain range and identify the key influential parameters. Furthermore, this study result contributes to the prioritization and optimization of future data gathering plan in Field A.
Wireline Cable Protection: Enabling Fluid Sampling in High-Risk Wellbores
Authors: Wheater Guy , Huyton Stuart , Miller Luke , Gerrity Russel , Ford Ronald 
Published: November 2018

Abstract
Wireline cable sticking is most frequently experienced during formation fluid sampling. In this situation, if the cable cannot be freed, strip-over fishing is the only remedy; this is a cost and risk-intensive activity which may extend the logging job by several days and result in further inefficiencies such as wiper trips or pipe-conveyed logging to fully satisfy the formation evaluation objectives. In this paper, the authors outline a proven engineering approach that permits the systematic identification of high-risk wells for cable sticking, where the deployment of wireline standoffs (WLSOs) may facilitate safe and efficient sampling on wireline.
The precursor of all cable sticking is slot cutting into mud-cake or formation. The slot is generated by sustained lateral pressure from the moving (tensioned) logging cable, referred to hereafter as "cable thrusts". A sophisticated 3D cable force model evaluates the cable contact zones and thrusts along the open hole section under analysis. For differential sticking, a cable contact and sticking limit in mud-cake is computed, having adjusted the pore pressures to offset data. For keyseating, the well is benchmarked against wells with similar trajectories, gained from a global study on cable sticking. Sticking-linkage is also assessed, whereby overpulls from tool sticking may induce cable sticking, via amplified cable thrusts against mud-cake or formation. To reduce cable sticking risks to an acceptably low level an array of WLSOs may be deployed, combined with optimised logging procedures and winch techniques.
Operators are now employing this approach on a regular basis as an important risk management tool, from the well planning stage through to completion. WLSOs have been successfully deployed for 40 sampling runs on 25 wells, in fields with a history of severe cable sticking or fishing. Prior signs of sticking have largely been eliminated, resulting in significantly reduced well costs, whilst avoiding pipe-conveyed logging or LWD, and without consideration to the value of lost data or samples. Well Engineering may now use this approach to design and optimize ambitious well trajectories, potentially saving a hole section, in the full knowledge that future wireline fluid sampling can be performed within the bounds of acceptable risk. Real-time risk assessments have proven invaluable, to track the risk trend as the well is drilled, leading to a final decision on the requirement for WLSOs, with additional optimisation of the sampling procedures if needed.
Operational best practices and lessons learned are summarized, as well as an outline for future R&D to understand and reduce wireline conveyance risks even further.
Installation of Reinforced Thermoplastic Pipe RTP as Permanent Gas Flowline
Authors: Al-Khabrani Mohammad A. , Parvez Anwar 
Published: November 2018

Abstract
Reinforced Thermoplastic Pipe (RTP) is a new technology that is reducing the cost of constructing oil and gas pipelines while improving reliability. RTP combines high performing materials such as bimodal high density polyethylene with high strength reinforcing fibers in a unique construction to create a high pressure pipeline system. RTP is corrosion-resistance component that require low maintenance and more cost effective compared to carbon steel. It will enhance the pipeline integrity and will open windows for corrosion inhibitor optimization in the system.
RTP has already been executed for the first time in Saudi Aramco for permeant natural gas transporting pipeline with elevated pressure and temperature parameters. The first application has already been installed at Southern Area Gas Producing Department (SAGPD) in a candidate gas well to pilot the installation and measure the performance of the 6″ RTP flowline for six months.
The primary benefit of RTP is realized by the installation methodologies available which contribute overall project savings of up to 30-50% for typical gas applications. Additional installation benefits include reduced right of way requirements, reduced safety hazards, and reduced environmental impact. Consequently, the utilization of RTP for new gas wells tie-in will significantly contribute in huge cost saving considering the high number of forecasted gas wells in the coming few years.
The main objective of this technical paper is to give an overview on the recent implementation of RTP pipe for the first time in sweet gas services applications in term of constructability and suitability.
Investigation of Smart Water Flooding in Sandstone Reservoirs: Experimental and Simulation Study Part2
Authors: Al-Saedi Hasan, N. , Flori Ralph E. , Mortadha Alsaba 
Published: November 2018

Abstract
In this paper, we considered the effect of water chemistry on water-rock interactions during seawater and smart water flooding of reservoir sandstone cores containing heavy oil. Oil recovery, surface reactivity tests, and multicomponent reactive transport simulation using CrunchFlow were conducted to better understand smart water flooding.
Secondary water flooding with FW at 25°C resulted in an ultimate oil recovery (UOR) of ~50% OOIP for all reservoir cores in this study. Formation water salinity was 104,550 ppm. FW was diluted twice to obtain SMW1. SMW2 was similar to SMW1 but depleted in divalent cations (Ca2+ and Mg2+). SMW3 was also similar to SMW1 but depleted in Mg2+ and SO42-, while SMW4 was the same as SMW1 but Ca2+ was diluted 100 times. Seawater salinity was 48300 ppm, which is close to the smart waters salinity (52275 ppm). No oil recovery was observed during SMW1 flooding, while softening SMW1 (SMW2) resulted in a significant additional oil recovery OOIP. Depleting Mg2+ and SO42- resulted in additional oil recovery but smaller than in SMW2. Diluting Ca2+ 100 times was the second best scenario coming after depleted Ca2+ in SMW2. The results of this study showed that the more diluted Ca2+ is in the injected brine, the more additional oil recovery that can be obtained, even though the other divalent/monovalent cations/anions were increased or decreased or even depleted.
Other reservoir cores were allocated for surface reactivity test. The absence of an oil phase allows us to isolate the important water-rock reactions. The Ca2+, Mg2+, and SO42- effluents for all cores were matched using CrunchFlow, and then further investigations of the water-rock interactions were conducted. The reactive transport model showed that decreasing the Mg2+ concentration will decrease the number of the most effective kaolinite edges Si-O- and Al-O-, but was not as pronounced as that in present of Ca2+, which explains why lowering Mg2+ concentration gives lower additional oil recovery, and why lowering Ca2+ concentration gives higher additional oil recovery.
Complex Reservoirs Characterisation Technique Based on Geological Seismic Conditioning and its Application in a Oilfield, Middle East
Authors: Xin C. , Zhaowei L. , Zhaofeng W. , Wenyuan T. , Yaliang X. , Yanjing L. , Xiaodong W. , Hongmei W. , Yu J. , Xiaohuan Y. 
Published: November 2018

Abstract
In order to improve the accuracy of reservoir prediction results, the conventional method usually include seismic inversion, and wei. Due to the limitation of the vertical resolution of seismic data, it is hard to identify the thin reservoir by seismic attributes directly. In order to improve the prediction accuracy of reservoir, this paper show a new reservoir characterization technique based on geological seismic conditioning. The new method mainly includes five steps. The first step is sedimentary facies classification based on the geological seismic analysis, such as core data, thin section analysis, FMI logging, NMR logging and conventional logging. The second step is modern sedimentary model optimization and forward modelling. In order to establish a reasonable sedimentary facies model, a similar barrier island modern sedimentary model was chose. To understand the geological significance of seismic data, two different dominant frequency were designed for forward modelling based on the sedimentary facies model and petrophysical analysis. The third step is seismic conditioning under the guide of sedimentary facies model forward modelling. The next step is seismic constraint stochastic inversion, and the last step is reservoir characterization and new well confirm. The application of this method in A oilfield shows that the techniques not only improved the identification ability of the reprocessing seismic data, but also improved the prediction accuracy of the reservoir characterization results. This new reservoir characterization technique can integrated multidisplinary information, such as modern sedimentary model, well data and seismic data, to establish a reasonable sedimentary model, to enhance the resolution of seismic data by conditioning, and get an reasonable reservoir characterization results based on the seismic inversion.
Rootzone for Oil Treatment and Recirculation
Authors: Løgstrup Jørgen 
Published: November 2018

Abstract
Transform has over the last 30years set up several projects for treating oil contaminated water and sludge. Special attention has been to treat and recirculate wastewater from car, container and train wash. With this experience it was decided to test and acquire an EU Environmental Technology Verification. Result of this test is that the specific developed Rootzone soil filter can adapt and decompose oil contaminant. It is documented that the treated water can be recirculated or reused for irrigation or other purposes. Approval from EU was given on the 9th of January 2018, as the first and only approval by EU of treating oil contamination. This presentation is the first given since approval.
Piloting Elastomeric Wraps for Protection of Offshore Boat Landing
Authors: Alshammari Sattam , Salazar Vidal Oscar Daniel 
Published: November 2018

Abstract
The scope of this paper is to describe the advantages of utilizing Elastomeric Wraps for repairing and protecting offshore boat landing piles located in the splash-zone, which is a challenge worldwide, and to make comparison between this new protective Wraps and our existing repair practice. With the aim to improve the capabilities of the boat landing to absorb impact energy by approaching vessels without structural failures and to enhance corrosion resistance at the boat landing piles. Currently, Safaniyah Offshore Department repairs corroded boat landings piles by welding half sleeves pipes to restore the thickness of the boat landing structured piles and then applying anti-corrosion coatings. This practice consumes significant execution time, requires hot working activities [e.g. welding] and has a limited durability [e.g. most boat landings require costly refurbishments and repairs every 3 to 5 years intervals]. Furthermore, most of offshore platforms have boat landings, which consume significant offshore maintenance resources [e.g. boats and barges time] to conduct necessary repairs for eliminating further damages to the platform structures. Due to these challenges, Elastomeric Wraps, induced-tension polymer Wraps, was piloted at a high traffic boat landing to test its capability to pass pre-determined success criteria, which include significant reduction in corrosion rates and higher level of boat impact resistance. The advantages of this design include cost saving, faster installation time, better maintainability, longer life service, improved anti-corrosion protection, higher resistance to boat impact and safe installation (no hot work required). The Elastomeric Wrap was installed in 2017 at a boat landing for the first time as part of the efforts to provide a permanent solution for protecting the splash-zone piles located in a very corrosive environment, and subject to potential mechanical damage from repetitive impacts by approaching vessels. This product is not only designed to mitigate the corrosion effects, it also protects against mechanical impacts at boat landings by Marine vessels [e.g. supply boats, maintenance barges]. The design also can be modified in the field as per specific-site requirements and dimensions, which provides additional flexibility for field maintenance. The rigorous criteria for considering the Wrap as a successful alternative are aimed at identifying area of deficiencies in the design stage during field trials and before approving the Wrap for maintenance of the boat landing. In short, the Elastomeric Wraps is developed for maintaining assets integrity, ensuring efficient utilization of company's valuable resources and safe operation for transferred personnel, crew vessels and supply boats, which is in line with Aramco Operational Excellence (OE) and Safety Management System (SMS) objectives.
Clair Phase 1: The Evolving Development of a Complex Fractured Field
Authors: Webster Mark 
Published: November 2018

Abstract
The Clair field is the largest discovered oilfield on the UK continental shelf (UKCS) but has high reservoir uncertainty associated with a complex natural fracture network. The field area covers over 200 sq km with an estimated STOIIP of 7 billion barrels. The scale and complexity of the reservoir has led to a phased multi-platform development.
Phase 1 started production in 2005 with 20 wells drilled prior to an extended drill break. Five new wells (A21 to A25) were drilled and brought online during 2016/17 which increased platform production by c.70%. The new wells incorporated historic lessons to mitigate the risk of wellbore instability in the overburden and be robust to the dynamic uncertainties of the fractured reservoir. Many of the well outcomes and risk events were predicted and mitigated effectively, however the new wells still provided some surprises.
This paper presents a summary of the lessons from the historic Clair development wells which underpinned the recent drilling campaign and additional field understanding provided by the new well results. New insights include a narrower overburden drilling window and zonal isolation challenges within the reservoir.
Use of FIDIC 2017 as Standard Form of Contract for EPC Projects in Oil and Gas Industry
Authors: Bidua Abhishek Kumar 
Published: November 2018

Abstract
Standard form of Contract for Engineering, Procurement and Construction (EPC) Projects in Oil and Gas industry has not gained the favor. Most of the NOCs/IOCs (National Oil Companies / International Oil Companies) prefer to use standalone bespoke EPC Contracts often based on in-house expertise that is developed from using the contents of different standard forms of Contract. This requires a lot of care during the drafting and several rounds of lengthy instructive discussions during the tendering. This paper discusses whether the use of Second Edition of FIDIC Form of Silver Book or Yellow Book released in December 2017 is possible as acceptable standard form of Contract for Oil and Gas Industry with the use of Particular condition to address the special requirements of a Project.
The EPC Contracts for onshore and offshore oil and gas projects are generally experiences the issues related to deficient scope definition, force majeure, performance related issues, indemnity, insurance provisions, change orders, termination, limitation of liability, no damage for delay etc. Second edition of FIDIC rainbow suite has striven hard to address the above stated issues with balance distribution of the risk.
The 2017 FIDIC Form of Contracts provides increased reciprocity between the Parties (i.e. Employer and Contractor) with an emphasis on notices and time bar provisions. Further, use of standard form of contracts such as FIDIC facilitates better understanding of the risks distribution at the outset of contract due to availability of precedence and accepted explanation of ‘terms and conditions of Contract’.
Evaluation of Gel Treatment in Fractured Reservoir Using Embedded Discrete Fracture Model: Experimental and Simulation Investigation
Authors: Alhuraishawy Ali K. , Wei Mingzhen , Alsubaih Ahmed A. , Bai Baojun , Almansour Abdullah 
Published: November 2018

Abstract
Preformed Particle Gel (PPG) have been used as conformance control in mature oil field. Reservoirs ith fractures and very high permeability are candidates for gel treatment. By injecting the PPG in the flooded area, the post waterflooding reached unswept area and improve oil recovery factor. Recently, Discrete Fracture Model (DFM) has been reached a great attention by some researchers in reservoir modeling area. Therefor, DFM was used to evaluation of gel treatment in fractured reservoirs using different senarios.
Outcrop carbonate core with oil-wet wettability was used to establish the experiment part. Transparent acrylic plates was used to design the fracrure model with 1.5 mm fracture width. Sodium chloride was prepared for waterflooding and PPG swollen. The experimental results showed that the preformed particle gel improved the oil recovery improved by 12% after gel treatment with 20% water cut reduction as an experimental results. Morover, the experimental result showed a very good match with simulation results in lab scale. The main PPG design variables are PPG concentration and PPG treatment timing according to the field scale simulation resuls and when gel treatment applied early, the oil recovery improved. The integration of gel treatment and Embedded Discrete Fracture Modeling (EDFM) will help the field developers to select the best senario for gel treatment.
Oil Gain from Successful Water Shut-Off Strategy
Authors: Ghatrifi Suhaib , Sulaimi Ghadna , Jimenez Chavez Maria , Sivrikoz Ayca 
Published: November 2018

Abstract
Water Shut-Off (WSO) actions are remedial activities that are being implemented in the heavy oil N Field, with the objective of reducing the water inflow of the well by closing zones which are major contributor to the high water cut. WSO are commonly executed as a mitigation action in operating wells with previous economic value. The purpose of this study is to develop a thorough knowledge of the rate of success of WSO activities linked to the time of WSO implementation, type of well (either horizontal or vertical) and the presence or lack of PLT (Production Log Test).
Success was evaluated by reviewing the net oil production rate before and after WSO activity with the gained net oil rate being converted to US Dollars.
There is no significant difference found in the success ratios between horizontal wells and verticals. However, in the horizontal wells, 74% of the successful ones were the heel shut-offs. WSO activities are found to have a success rate of 100% if the activity is implemented within the first year of the start of high water cut. Moreover, wells with WSO implementation within the first three years of observing high water-cut have a success rate of 65%. Noticeably, the success rate decreased dramatically with time, with wells having high water-cut for seven years and up to eleven years to the time of WSO implementation. These wells show success rates of 50% and 33% for seven and eleven years respectively.
A numerical sector model and well model were created to explain these findings. During oil production because of a localized decrease in pressure, the water-oil interface may rise up and deform into a conical shape near the well. This phenomenon is known as ‘water coning’. At the time of water breakthrough, the cone is observed to be narrower than more advanced stages when the water cut has risen to higher levels. At these times, the cone has broadened and, depending on spacing between adjacent wells, has lifted the overall level of the oil/water interface, decreasing the distance between the wellbore and the water. As a result, water shutoff becomes less effective with time.
It is recommended to start WSO activities on wells within the first three years of high water-cut indications. In case there is no PLT or other data, heel shutoff for the horizontal wells have a better success rate.