bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Model for Predicting Productivity Index Pending Water Breakthrough in Oil Field
Authors: Yang Renfeng , Zhang Jinqing , Yang Li , Jiang Ruizhong 
Published: November 2015

Abstract
It is believed that the productivity index (PI) of vertical, horizontal, hydraulic fractured, or multilateral wells is considered to keep stable before water breakthrough. However, PI changes and presents different characteristics several months before water breakthrough, especially pending water breakthrough. If no measure is taken, the production rate will not keep stable. This condition has not aroused enough attention. Furthermore, there is currently no model for predicting which could reduce production forecasting accuracy.
Based on Buckley-Leverett equation, material balance equation and Corey-type functions for relative permeability, a new model for predicting productivity index was derived. It considers oil/water viscosity ratio, relative permeability, permeability, porosity, net pay, water injecting rate, well space, etc. Complete equations are provided and the method is described in detail to permit readers to replicate all results.
The most significant new finding is that the characteristics of productivity index pending water breakthrough depends on the relative filtration resistance changing rate with calculating the derivative of filtration resistance function. The productivity index monotonically decrease pending water breakthrough in volatile oil reservoirs, especially when the oil viscosity is less than water, while it monotonically increases in heavy oil reservoirs. Moreover, there are breakpoints in some medium viscosity reservoirs. It is found that the key influence factor is a function related with relative permeability and oil/water viscosity ratio. Based on mathematical analysis of mechanics equation and more than 100 simulation runs, it can be concluded that the permeability, porosity, net pay, heterogeneity, water injection rate, well pattern, and well space don't change the rules, but influence the initial value and change rate. The proposed model has been validated using production data from many oil wells and several reservoirs with a wide viscosity range.
The novelty of the new model is that it can be used to quickly and accurately predict production rate pending water breakthrough without involving time consuming simulation technique. Corresponding measures could be taken in time when PI begins to change in order to improve the development efficiency.
Contribution of Fluid Cleanliness to Smooth Gas Plant Commissioning and Start-up at GASCO's Habshan 5 Integrated Gas Development (IGD)
Authors: Trifilieff Olivier , Gardin Alessandro , Tecnimont Maire , Al Maskari Saleh Mohamed 
Published: November 2015

Abstract
The Habshan 5 Process Plant (H5PP) is one of the four packages that constitute the GASCO Integrated Gas Development (IGD) Scheme. The JGC-Tecnimont Joint Venture was awarded the EPC phase. The project was completed on schedule within 50 months, and the plant was successfully handed over in September 2013. One of the key contributions to the smooth plant commissioning and start-up is the choice made by the JGC-Tecnimont JV and GASCO for fluid contamination control. In the form of liquid aerosols and solid particles, contamination in process gases and liquids represents a major contributor to operation issues in gas processing units, such as foaming. A strategy for fluid cleanliness control was implemented to keep fluids clean: supported by PALL from the design phase, the specification and the selection of filter and coalescer technologies at critical contaminant-challenged locations were made carefully. Appropriate activities during prefabrication, precommissioning and commissioning phases were implemented to minimize contamination from installed equipment. Performance tests carried out at start-up on the main coalescer and filter equipment confirmed that clean process fluids were delivered and compliant separation efficiencies were achieved.
Geomechanical Heterogeneity Diagnosis of Carbonate Reservoirs in Onshore Abu Dhabi
Authors: Sirat Manhal , Noufal Abdelwahab , Simon Janelle , Zhang Xing , Subbiah Surej Kumar 
Published: November 2015

Abstract
The main objective of this paper to is to discuss the recent finding on the formation anisotropy and lateral heterogeneity in the different hydrocarbon fields of onshore Abu Dhabi. The study was focused on Thamama and Wasia groups, mainly related anisotropy and spatial heterogeneity of the geomechanical poperties for reservoir characterization. This would have an impact on the stress variation and the definition of potential "sweet spots" for well placement optimization and identification of suitable completion methods.
The 1D Mechanical Earth model (MEM) is a description and quantification of rock elastic and strength properties, in-situ stresses and pore pressure as a function of depth, referenced to a stratigraphic column. The available wireline logs of several existing wells, including the compressional and shear slowness, stonely, bulk density, and gamma ray were used to compute log-derived elastic parameters, strength properties and stress components. Rock mechanics laboratory core plug tests were performed to calibrate the log-derived mechanical properties. Anisotropic modelling was applied to understand the anisotropy in elastic properties and horizontal stresses.
Integrating the 1D-MEMs indicate that Onshore Abu Dhabi Geomechanical properties (elastic and strength) and in-situ stresses vary laterally and vertically. Further, several mechanical layering and horizontal stress anisotropy can be identified. These results imply that the Wasia and Thamama reservoirs are susceptible to different fracturing mechanisms. Hence different fracture and faults sets can be predicted within the highly anisotropic deformation zones.
These findings significantly impact the exploration play concepts, where lateral variations are anticipated. This also applied to the production and development, where the stress barriers control the stimulation and completion strategies.
Towards Predicting Multi-Phase Flow in Porous Media Using Digital Rock Physics: Workflow to Test the Predictive Capability of Pore-Scale Modeling
Authors: Masalmeh Shehadeh K. , Jing Xudong , Roth Sven , Wang Chenchen , Dong Hu , Blunt Martin 
Published: November 2015

Abstract
Digital rock physics (DRP) has gained significant development in the last decade. At its current state, in general DRP cannot yet reliably a priori predict two-phase fluid flow properties without knowledge of wettability/contact angles, especially for non-water-wet rock. Prediction of two phase flow properties becomes even more challenging for carbonate rocks which are rarely water-wet and have a complex pore structure. The two main challenges are to model pore geometries and size distributions at a representative elementary volume (REV) and the representation of wettability. Advances in micro- and nano-CT imaging and computer capability may help solve the first challenge, although the translation from images to model input parameters and REV consideration remains a research topic. However, wettability distribution (as an input parameter) cannot be predicted and will remain to be the most significant problem in attempting to predict multi-phase flow properties.
In this paper, we study the use of pore-scale imaging and modeling (DRP) to predict relative permeability curves. We recommend that we should shift focus from a priori prediction of fluid-flow properties, to instead investigate how much experimental special core analysis (SCAL) and imaging data is required as input to calibrate or constrain the model before computing two- or three-phase flow properties for field applications. In this paper we will focus on two main issues: 1- The role of DRP and how it can complement SCAL data, 2- How can we improve the predictive capability of DRP through the use of imaging data combined with benchmarking and tuning to match core-scale measurements. A case study and a recommended workflow to integrate DRP in the whole SCAL procedure is presented. In the case study, the measured primary drainage capillary pressure is used to modify the pore size distribution inferred from multi-scale imaging, while the waterflood capillary pressure is used to estimate contact angle. Then waterflood relative permeability is predicted and compared to experimental measurements: the water relative permeability lies within the range of measurements made on four core samples, while the oil relative permeability is over-predicted.
The core samples used in the study are carbonate samples; however, the workflow described in the paper applies to both sandstone and carbonate rock. The workflow relies on using DRP as a complementary and integral technology to conventional SCAL that might help to reduce cost and fill some gaps instead of replacing SCAL.
Realization of Over Half a Billion USD Worth Centrifugal Compressors for Mega Oil & Gas EPC Projects
Authors: Remy Philippe , Mossolly Mounir 
Published: November 2015

Abstract
Mega oil and gas projects have become more frequent as scale has increased and as resources in increasingly remote locations are produced.
Despite the harsh operating environments, the size and complexity of these projects are unprecedented. Contractors must; and are still expected to deliver their commitments as per the specifications, within budget and on-time. Technological novelty is avoided where possible but in cases such as the one discussed in this article it must be managed.
When it comes to ethylene and LNG, turbo-machinery; and in particular centrifugal compressors, are the core of such projects involving sophistication, cutting-edge technologies, and specialty know-how. Being custom-made to project specifications and operational requirements makes their successful realization a unique technical journey and a serious technological and managerial challenge.
In some cases centrifugal compressor shaft lines extend to 50 meters long with a rotating mass reaching hundreds of metric tons turning at a speed close to 3600 rpm, for compressing millions of kilograms per hour of process gas, all happening with vibrations levels barely felt by human sensation.
Such shaft lines are designed and engineered with latest simulation tools, verified with most advanced rotor-dynamic and aerodynamic models and software, manufactured to the most precise and accurate tolerances and rigorously inspected and tested for full trouble-free functionality.
The total cost of such compressor strings as part of a compression system in an LNG plant may reach over half a billion USD. The resources required involve hundreds of experts, specialists, engineers and technicians, and accordingly their realization is far from being a usual task.
This paper present the best practices and some of the know-how that have been progressively learnt, refined and implemented through the execution of several projects of this kind.
Asset Lifecycle Information Management as a Service
Authors: Koumpan E. , Noller D. , Kaijim W. , Webb G. 
Published: November 2015

Abstract
The Chemical and Petroleum (C&P) Industry is waking up to the power of data to create more value, reduce cost, and gain competitive advantage. When dealing with Major Capital Projects (MCP), we have seen an increasing transition from paper to digital, from stand alone to collaborative, from product to outcome, and from CAPEX (capital expenditure) / OPEX (operational expenditure) to TOPEX (total expenditure). This includes a shift from the traditional engineering, construction and handover to the owner/operator lifecycle and, ultimately, to the full asset lifecycle. The extended asset lifecycle and more, as well as new requirements to manage, have increased complexity. This is mainly do to more disciplines needing to work together in an integrated way using a shared asset information model
Data is the new natural resource. The amount of data the Engineering, Construction and Operation (EC&O) processes and activities produce, is authored in many different systems and consumed by many organizations and users in different formats. Not only is capturing their own data in their own systems of record (SOR) important to the C&P Industry, but so is external data, including unstructured data. The combination of SOR data with extended data can create additional value and provide new insights for better decision management.
Another complication is the fact that the EC&O processes of large scale Major Capital Projects have changed. Delivery today is typically divided across multiple organizations, and supported by multi-level supplier networks, in order to share the risk.
Optimizing Oil Development of a Super K Compartmentalized Reservoir with Large Gas Cap and Bottom Water Aquifer Case Study
Authors: El Gazar Ashraf , Bin Sumaidaa Saleh A. , Alklih Mohamad Yousef , Syofyan Syofvas , Al Shabibi Tariq Ali 
Published: November 2015

Abstract
This paper presents a case study of developing a significant volume of super K compartmentalized oil reservoir with a large gas cap and bottom water aquifer in Abu Dhabi-UAE. The reservoir is a low relief heterogeneous carbonate, located in a complex environment represented by natural and artificial islands in the surface, shallow and medium water marine areas with subsurface lateral, and vertical heterogeneities as well as variation in reservoir fluid properties.
The static and dynamic data were utilized to construct representative geological and dynamic models for the reservoir. The field development objective focused on maximizing the oil production and achieving 70% RF while minimizing the gas cusping, water conning and early breakthrough via super K interval.
Nine years production dynamic data were available from 6 oil producers in addition to well testing "14 wells", core "11 wells", MDT "17 wells" data during the appraisal phase. These data were used to quality control the initialization and history match phases. In preparation to the development options, the team included pressure support using water injection, lean gas injection, miscible gas injection, miscible WAG injection. The predicted reservoir performance of the super K oil reservoir indicated considerable gas production and high water production from the bottom water aquifer through super K interval in all the development options.
It was a big challenge to reduce the amount of gas production, water production, and early breakthrough for all development options. A new development option was introduced to perform peripheral miscible Hydrocarbon WAG injection accompanied with optimization of the wells and completion intervals locations for producers and injectors, as wells as WAG cycle to minimize the gas production from the gas cap, water production from the aquifer, and early breakthrough. This resulted in significant enhancement to plateau length, sweep efficiency, and recovery factor.
This paper provides the methodology followed to guide the development plan to fill in the uncertainty gap along with a detailed data acquisition and monitoring programs to better understand the reservoir behavior.
Successful Implementation of Sidewall Coring: 1st Trial in UAE
Authors: Mahmoud Gehad , Snaineh Bashar Abu , Steiner Stefan , Monson Eric , Shrivastava Chandramani 
Published: November 2015

Abstract
With the ongoing trend of E&P companies worldwide, there is currently an increasing pressure to tap the unconventional resources in the UAE as well as try to optimize well costs. Petrophysical evaluation of these reservoirs requires non-standard measurements. In this paper we will present how this approach was successful in utilizing the Side Wall Coring technology for the first time in ADCO fields.
This job required understanding what studies can be conducted on the acquired core plugs, as well as the operational planning and risk assessment to ensure a safe and successful operation. Two runs were planned on wireline due to maximum capacity of 50 core plugs per run.
A coring program was designed to investigate the potential of these source rocks formations. And we managed to get 88 side wall cores (with a total length of 2 in by 0.92 inch diameters) with a recovery of 100% in two wireline runs. The coring operation was conducted in 12-1/4'' hole. The program was adjusted to record the log with less under balance, and before increasing the mud weight to avoid the risk of differential stuck by wire line while conducting the operations. Core analysis results are presented to show the importance of the acquired data.
This paper describes the first side wall coring job conducted in the UAE. This includes planning, risk assessment, the core handling procedures, and lessons learned. A cost-benefit analysis is presented in which the applied coring technology has been compared to conventional coring
Beyond Compliance: Reduction of Emissions and Effluent Discharges
Authors: AlHanaee Shaikha , Ibrahim Muneef , ElHendawy Mohamed 
Published: November 2015

Abstract
Vertical well bores are drilled thousands of feet into the earth through sediment layers, the water table, and shale rock formations in order to reach the oil and gas. The drilling is then angled horizontally, where a cement casing is installed and will serve as a conduit for the massive volume of water, fracking fluid, chemicals and sand needed to fracture the rock and shale. In some cases, prior to the injection of fluids, small explosives are used to open up the bedrock. The fractures allow the gas and oil to be removed from the formerly impervious rock formations.
Pollution occurs from entry of foreign materials into air, water and/or ground. In marine environment many toxic chemicals convert to tiny particles which are then taken up by plankton and benthos animals. In this way, the toxins are concentrated upward within food chains. Many particles combine chemically in a manner highly depletive of oxygen, causing water to become anoxic.
In this context, for NDC, the adoption and implementation of a vigorous Environmental Management System (EMS) is paramount. The company is an ISO-14001 certified, therefore, it embraces an effectual process for evaluating the aspect related to its operations. This process is in accordance with ADNOC code of practices (ADNOC COPs), which are the general framework of all ADNOC groups of companies.
New Optimized Slot Recovery Method
Authors: Al Darkazly H. S. , Karrani S. , Al-Marzouqi A. , Khamis A. , Mukai N. 
Published: November 2015

Abstract
Slot recovery method has been applied in drilling industry. However, the current techniques have limitations in terms of cost efficiency, uncertainty of operation duration and limited to wells with integral conductor casing. The new slot recovery method can overcome all the above limitations with additional benefits to the new well. The new method is simple and environmentally friendly that can be applied under the HSE standards worldwide.
The method is to run hallow bit with diamond cutters. Clean the cement between the 30 inch conductor and the old 36 inch hole to 50 feet below old conductor shoe. Cuttings will be returned to sea bed, after cleaning cement, casing cutter will be run in to cut the 13.375 inch casing from inside to 50 feet below the conductor shoe. Afterwards, the casing spear will be run and latch internally in the 9.625 inch casing and then the casing is pulled out to rig floor. The casing is then secured and cut into intervals. As a result, after pulling the conductor pipe will have 37 inch empty hole. Cement string will be run to spot the cement plug inside the 37 inch Hole, and then dress the top of cement to the planned new 30 inch conductor shoe. Run new conductor and utilize the cement plug to kick off for the next drilling phase.
By using this method in slot recovery, the new well would have new conductor and no risk of old corroded conductor. The operation time guaranteed to match with planned days with estimated saving of 20 days compared to old methods. The cost saving is estimated USD 3 Million $ per well. Moreover, no more heavy milling that requires milling fluid and containers to collect the steel cuttings. By saving the time and cost, re-entry wells can be switched to slot recovery for achieving more sweet targets and insure long term well investment. The slot recovery wells can be drilled as dual string compared to single string in some cases of re-entry where casing size is a limit. The new method is simple to apply by rig crew, no need for service engineer and consumable mills. Utilizing this method to change wells from re-entry to slot recovery and hence enhancing oil recovery is a new approach of cost optimization.
Modelling for Safe Operations
Authors: Read Peter , Pushkarna Arun , Al Katheeri Z. A. , Al Rashedi H. , Ibrahim W. A. 
Published: November 2015

Abstract

Objectives/Scope
Problems in operations are not unusual to drilling. When a problem cropped up during drilling operations in the artificial islands and started manifesting itself in broken bolts, dropped objects, etc it posed a risk to the safety of personnel as well as integrity of operations frustrated staff from the OPCOs, Service Companies and Drilling Contractor examined their equipment while safety continued to be threatened with serious vibrations resulting in continued incidents of high potential dropped objects from heights.

Methods, Procedures, Process
The Drilling Contractor took the proactive step of resorting to modelling the rig and assemblies with the involvement of experts from a reputed University. The objective was to scientifically identify the reasons behind the undesired occurrences and seek solutions for safer operations. A continuum model was utilized and the drill string modelled to simulate the site conditions. The impact of the various positions oft he bottom hole assemblies was examined in the model and the results recorded to get a deeper understanding of the effect of these. Additionally the stiffness values were changed to simulate different Bottom Hole Assemblies.

Results, Observations, Conclusions
Surprisingly what was earlier thought of as a problem with the mast and the Topdive was eventually revealed as a problem with the type of bottomhole assembly which was giving rise to whirl and causing the mast and Topdrive to vibrate as a consequence. The modelling not only identified the root cause of the problems but even offered solutions to the problem. It gave an unexpected benefit by establishing a better, safer solution for performing drilling operations without risk of damaging vibrations.

Novel/Additive Information
The approach has opened up a completely new vista of operational safety and provided the tools for safe operations by allowing all involved parties to test any combination of downhole tools before deployment thus eliminating operational risks, improving process safety and operational efficiency.