bluuebunny/crossref_metadata_2025_split huggingface dataset:
Impact of Imbibition Mechanism on Flowback Behavior: A Numerical Study
Authors: Almulhim A. , Alharthy N. , Tutuncu A. N. , Kazemi H. 
Published: December 2014

Abstract
Horizontal drilling and multi-stage hydraulic fracturing are among key technologies that enable the oil and gas industry to unlock unconventional resources. Water-based fracturing fluids are commonly used in massive volumes to hydraulically crack shale formations and transport proppant to keep open the newly created fractures. After hydraulic fracturing implemented to stimulate a well, the clean-up process takes place by flowing back the well. Most shale reservoirs tend to trap and retain the fracturing fluid (water) in the small pores and microfractures ending with a water flowback which typically not exceeding 50% of the injected volume. The water imbibition mechanism by capillary forces can help explaining the reason behind the retained water in the shale matrix and the dynamic water saturation re-distribution during the shut-in time.
This paper investigates various effects, such as rock wettability, well shut-in time, capillary pressure and natural fracture intensity on the flowback behavior and the ultimate production performance. The specific emphasize was given on brine imbibition as a vehicle to improve gas permeability and the overall gas recovery. It was shown that spontaneous capillary imbibition in strong water-wet formations forces water into the matrix and eliminate water blockage in the fractures while in weak water-wet formations, more water stays in the fractures causing a delay in gas production.
Optimizing Well Bore Safety in the Mishrif Formation by Installing Bi-Directional Downhole Barrier Valves
Authors: Wickramasinghe Tharinda , Aliyev Aslan , Chen Igor 
Published: December 2014

Abstract
This paper describes the challenges faced when completing wells in the Mishrif formation of Southern Iraq, where well control concerns increase post acid stimulation of the reservoir due to the unpredictability of the formations behavior.
One of the biggest challenges faced when drilling and completing in this formation is to manage a natural hydraulic balance of the reservoir to avoid the well switching from losses to kicks without warning. While this challenge is being addressed by carefully selecting drilling and completion fluids of specific densities, it has not been fully mitigated as wells have shown signs of switching state arbitrarily specifically post acid stimulation operations. In light of this challenge Weatherford had proposed a completion design that would incorporate a downhole bi-directional barrier valve which would ensure that the well bore would be secure upon installation of the lower completion. It was envisaged that this technology would help overcome any dynamic changes of the reservoir that may lead either to fluid loss, risking damage to the reservoir or kicks risking a catastrophic blow out.
A typical production well architecture in the Mishrif formation of the West Qurna-2 field would consist of 9-5/8″ production casing to surface and an 8-1/2″ Open Hole section that would be completed with either 7″ slotted or perforated liner. Well trajectories could vary from vertical to a maximum deviation of 60 degrees in most cases. The proposed design was to complete a few of the early phase wells using 9-5/8″ × 5-1/2″ mechanical ball valves incorporated into the lower completion which would therefore serve as a bi-directional barrier once installed and shifted closed.
Combining Development with Environmental Friendly Solution (GASCO Artificial Islands)
Authors: AL Hosani Jasem 
Published: December 2014

Abstract
The paper presents a case study from Abu Dhabi, UAE where a new navigation channel needed to be dredged to satisfy the growing demand of a Sulphur Handling terminal. The project is located in the UAE where the creation of a navigation channel was needed to satisfy the demand of a Sulphur Handling terminal. The creation of the channel required the dredging and disposal of approx 19 million m3 of dredged material.
This paper presents a case study of the decision making process and design phases that were performed to ensure that the channel can be created in a fast, efficient and environmentally friendly way.
The UAE has gained international recognition due to the large scale and rapid construction of its massive projects in coastal and marine areas. With Abu Dhabi's ever growing oil and gas industry, new terminal, ports, navigation channels and jetties are constantly being developed, creating design, environmental and construction challenges.
Simulation of Miscible Gas Injection in a Fractured Carbonate Reservoir using an Embedded Discrete Fracture Model
Authors: Panfili P. , Cominelli A. 
Published: December 2014

Abstract
A large proportion of world's oil reserves resides in naturally fractured reservoirs. Implementing IOR and EOR processes in these reservoirs is a high risk/high reward activity. For instance, on one side water/gas may rapidly break-through along fracture corridors and then jeopardize the IOR/EOR scheme results. On the other side, fracture networks may effectively promote gas-oil gravity drainage or spontaneous imbibition. Accurate and efficient simulation of fractured media is a recognised challenge for reservoir simulators.
Various approaches, with different balance between efficiency and accuracy, have been proposed in literature. Up to now the most diffused methods to deal with fractures, have been the adoption of a Dual Porosity/Dual Permeability (DPDK) formulation in a logically structured grid, or the use of unstructured grids.
In this work EOR processes in a fractured reservoir were modeled using the Embedded Discrete Fracture Model (Li and Lee, 2008). EDFM represents a practical and efficient compromise between DPDK and unstructured gridding, combining a corner point geometry grid for matrix and an unstructured network for fractures. EDFM was implemented using commercial simulators.
The target of the work was sour gas reinjection in a carbonate reservoir characterised by a matrix dominated platform and a fractured rim, with some transition between these two environments. The input of the study was a discrete fracture network, developed using seismic curvature lineaments, and a geological model for the matrix. EDFM and DPDK models were first compared. Then, the new approach was used to investigate fracture impact as a risk for premature gas break-through. The results indicated that the containment of the injection inside the platform, possibly far away from the rim, is an effective way to control the EOR process.
Automatic Subsea Deduction Well Testing for Increased Accuracy and Reduced Test Time
Authors: Idsø E. S. , Sperle I. L. , Aasheim R. , Wold M. S. 
Published: December 2014

Abstract
High quality well tests are important for allocation, updating of reservoir models, daily production planning and optimization. Increased accuracy of well tests can enable production optimization at gas- or water-limited fields. An automatic deduction well testing method developed in collaboration between the asset and Statoil RDI (Research, Development and Innovation) is presented in this paper.
Subsea wells without a dedicated test flow line are normally tested by manual deduction well testing; i.e. the test well is choked back, and the resulting change in the common flow line is used to calculate the contribution from the test well. During the test, the flow rate from the other wells on the common flow line should be as constant as possible. As the total flow rate reduces, the back pressure for the other wells on the same flow line is reduced, and, if no other action is taken, the flow rate from the other wells on the test line will increase. The manual procedure to compensate for the pressure change is to adjust the well head chokes so that the well head pressure, and hence the flow from each well, is kept close to their initial values. The manual test method has about 10% deviation in actual flow, is time consuming and demands high attention from operators.
This paper describes development and application of an automatic deduction well testing method to improve well testing. The method was implemented and tested with good results at the Midgard and Mikkel subsea fields, tie-ins to the Statoil-operated Åsgard B production facility, in December 2012. In the automatic method, the well head pressure, and hence the flow rate from the other wells on the test line, are kept close to constant. The accuracy was improved to less than 1% deviation in actual flow, the test duration was reduced by 20–30%, and the operator work load was significantly reduced. The automatic deduction well testing method has been successfully repeated at the field every six months since the first test, and is currently being implemented at several other Statoil operated fields.
Successful Deployment of new Extended RockstrongTM Coring System: Record Coring Delivery and Recovery Achievement in ADCO Exploration well – UAE case History
Authors: Akinlosotu A. O , Reyami M. , Tipu I. , Said I. , Mahmoud G. 
Published: December 2014

Abstract
This paper presents how extensive pre-job planning and proper utilization of new technology led to actualizing the coring objective of a well safely including successful coring through the hydrogen sulphide (H2S) rich Habshan 1 and 2 formations in an onshore field of the Abu Dhabi Company For Onshore Oil Operations (ADCO) in the United Arab Emirates.
Well AK1 is part of a wider field appraisal plan to be used for data gathering and building a conceptual field development plan. The challenges were multiple, not only from the planning and coring bottom hole assembly (BHA) design point of view, but also in terms of effective health, safety and environment management during execution posing environmental and technical challenges to the desired data gathering objective.
The appraisal well AK1 well design required 12 conventional coring BHA runs over a 27days duration including coring with an 8–1/2" coring BHA through a 12–1/4″ hole section. With detailed forward planning, use of new extended coring technology, operational focus and health, safety & environment (HSE) consciousness at the forefront, 6 continuous cores in 15 rig days with a record total core length in excess of 1,300 ft was successfully cut with 100% recovery factor through Shilaif, Mauddud, Top Nahr Umr, Unit 22a, Unit 22, Habshan, Habshan 1, Habshan 2 and Dense below Habshan 2 formations with H2S contents way in excess of safe limits saving 12 days rig time and almost $1m USD of planned well cost in the process.
This paper aims to share how this was recently achieved highlighting some of the challenges faced in terms of planning and sharing the experience gained from successful execution of well AK1, including coring through H2S bearing formations, with respect to optimized core acquisition and handling for the benefit of other operators in the region.
Steerable Drilling Liner Technology Successfully Mitigates Formation Stability Issues
Authors: Eidem Morten , Grindhaug Gaute , Spreckelmeyer Niko , Regener Thorsten , Clemmensen Carl C. 
Published: December 2014

Abstract
The Steerable Drilling Liner is an integrated drilling system that combines the advantages of rotary steerable drilling- and logging-technology with the liner drilling concept. This allows drilling complex 3D wellpaths with the same logging and directional capabilities as a conventional drill string, enabling operators to drill and secure the wellbore with a liner in one continuous operation. The technology has been successfully applied in several drilling operations and has been recognized as a method to overcome stability challenges in unstable formations.
The technology offers the following benefits compared to conventional drilling:
Reduced initiation of formation instability due to: – Reduced hydraulic surge (no tripping in open hole) – LBHA/drill-string always tripped in cased hole also when a bit trip is required – Reduced mechanical load on borehole wall – Low rotational speed (~30 rpm) and fully centralized liner with "non-rotating" centralizers prevent mechanical interaction between pipe and borehole wall. – Low shock and vibration effects due to low rotation speed reduce risk of tool failures Reduced time consumption and open hole time: – Remove time between drilling and lining of formation. Wellbore secured before collapse processes start – Reduced operational time as reaming, back-reaming, wiper trip or general wellbore conditioning are not required for successful liner installation
This paper will elaborate on the Operators Steerable Drilling Liner technology experiences. Focus will be on the mechanisms why Steerable Drilling Liner is an enabling technology when used in unstable/troublesome formations, compared to conventional drilling methods. It will also describe expected future utilization and applications and finally touch upon the next generation SDL system, which currently is under development.
Capillary Pressure and Relative Permeability Assessment on Whole Core Samples from a Giant Middle Easteren Carbonate Reservoir Utilizing Digital Rock Physics
Authors: Koronfol Safouh , Grader Avrami , Suhrer Michael , Toelke Jonas , Mu Yaoming , Dernaika Moustafa , Pratap Mahendra , Al Hamadi Mohammad , Al Ratrout Ahmad , Kalam M Zubair 
Published: December 2014

Abstract
Digital Rock Physics (DRP) has significantly evolved in the last few years and added invaluable contributions in improving core characterization and in providing high quality advanced SCAL measurements, emphasized through various studies/papers (SCA-2012–03 Kalam et al). This paper represents a unique DRP SCAL study that includes primary drainage capillary pressure (Pc) as part of Swi establishment and relative permeability (Kr) measurements done on four whole core (WC) samples from two different carbonate formations with a stylolite layer in between. The aim of the study was to evaluate how DRP results would compare with physical SCAL measurements done – on the same WC samples as a composite, as well as on plug samples from the same formations/layers – in a leading international core analysis lab in USA. The DRP results were up-scaled to the individual WC level and compared with the SCAL results from the corresponding layers. The DRP technology in this study also provided the capability of up-scaling the results to the WC composite which was used by the lab to assess the effect of the stylolite layer on the water flood. The comparison showed excellent matches between the physical and DRP-derived Pc and Kr data. The paper outlines the DRP methods used to determine the SCAL properties of the three formations. The laboratory measurements of SCAL properties took six years while the DRP work that followed blindly (without any knowledge of the laboratory results) was completed in six months. This demonstrates the effectiveness of the DRP technology in providing high quality SCAL data in a timely fashion regardless of sample size. Impact of possible wettability changes and sensitivities on one of the WC composite constituent component was also easily established unlike the high risk laboratory tests. This is the first water-oil displacement validation study results on reservoir whole cores of four inch diameter at full reservoir conditions using DRP.
Innovative and Cost-Effective Coring Technique Extended Coring for Long Intervals of Multiple Zones with World Record – Case Histories from the UAE
Authors: Hegazy Gehad Mahmoud , Salem Adel M. , Shedid Shedid A. , Aftab Muhammad N. , Ali Muhammad , Al Riyami Mazin , Hazem Wahab , Mohamed Farouk 
Published: December 2014

Abstract
Continuous core acquisition across formations of interest to perform quantitative and qualitative analysis is extremely important for exploration geologists and reservoir engineers. Measurements performed on cores are typically calibrated against well logging data for accurate and better reservoir interpretations. However, the coring cost is directly proportional to coring technique, core length and a significant part of coring cost is associated with rig time. In deep formations, the coring cost becomes extensively high due to multiple trip times required after each conventional coring run (90 ft). The best way to minimize the coring cost is to reduce the rig time efficiently achieved by reducing the number of trips required to acquire core.
Abu Dhabi Oil Company for Offshore Oil Operations (ADCO) has recently investigated different coring scenarios and technologies to optimize the coring operation time. An innovative and cost effective solution was developed and applied as a result of this investigation by Extended Coring (Long Barrel) which meets ADCO's objective of continuous coring across formations of interest. This procedure reduced number of trips, rig time and eventually drilling cost. The extended coring (Long Barrel) can be run in lengths from 120 ft to 810 ft with proper timing and planning for the jobs.
This paper describes ADCO's new strategy of extended coring (long barrel) acquisition based on formation's geological description. The case histories of extended coring in different formations in 8 ½" and 6" hole size sections, the core handling procedures applied and lessons learned in a continuous iterative process to optimize drilling cost in future operations are presented and analyzed.
Information Technology Applications in Construction and Oil and Gas Projects Management Performance – Future Vision
Authors: El Ghandour Wael 
Published: December 2014

Abstract
In recent years more and more construction projects used information technology applications to support execution and management tasks. However, construction companies in the world and accordingly in UAE still wrestle with information technology applications in construction (ITC) and how they could be effectively applied on their specific projects. One main reason for this struggle is that an account about how ITC have been used in the past or could be used in the future is missing. This research aims to provide new impetus to UAE's growth and competitiveness in construction engineering and management areas.
The paper presents some areas that ITC could be applied in oil & gas construction sector of UAE. It offers practitioners such an account of the application areas of ITC technologies including the purposes for which these technologies have been applied. The paper qualitatively aggregates the results of more than 200 papers to show how ITC have been applied to address different projects challenges. The paper presents samples of key practical areas for simulation modelling applications in construction industry that are proposed by author for oil & gas projects. The main finding of this analysis is that ITC could play significant role in controlling key indicators of oil & gas construction projects performance including, but not limited to, schedule, cost, safety, quality, team work, and scope management. It could help project managers solving critical concerns such as claim analysis, cash-flow optimization, resources optimization, camp management, and many others.
Risk Based Inspection Implementation for Upstream Offshore Operator: Case Study
Authors: Matthews Steve , Al Jaberi Manea Saeed , Mundyath Devadas 
Published: December 2014

Abstract
A risk-based inspection (RBI) programme, covering ZADCO's offshore production and onshore processing facilities, has recently been completed. The scope of work, which included over 25,000 items of static pressure equipment, piping, relief valves and pipelines, had key objectives of reducing the risks to personnel, the environment and to the business through compliance with a regional, corporate Code of Practice for the identification and integrity assurance of health, safety and environmental critical equipment and systems (HSECES).
The RBI programme for static equipment and piping, which comprised over 80% of the total equipment count, was carried out in two phases: Phase 1, a screening phase, comprised qualitative risk assessments at the system level; system risk was based on the worst-case combination of failure likelihood and loss of containment consequence applicable to that system. Equipment and piping within low risk systems were allocated generic inspection plans, consistent with equipment type and materials of construction. Phase 2 comprised semi-quantitative risk assessments of the remaining equipment and piping within medium and high risk systems. All credible degradation mechanisms were separately risk ranked and inspection plans were allocated, based on relevant degradation mechanisms, equipment type, accessibility, materials of construction, internal lining/cladding and insulation status. Both phases of the RBI implementation were backed-up by a series of multi-disciplinary workshops during which the initial assessments were subject to rigorous challenge and review.
This approach has enabled ZADCO to fully implement RBI in a timely and efficient manner, with the screening phase, in particular, facilitating appropriate focus on current and emerging integrity threats to the facilities. A key element of the programme was the development of an RBI methodology and configuration of software to integrate much of ZADCO's existing integrity management practices with an innovative, efficient approach to risk assessments and inspection planning.
Multi-Lateral Wells with Downhole Water Control and Disposal in Heavy Oil Reservoirs with Bottom Water – A Case Study
Authors: Alblooshi Younes A. , Wojtanowicz Andrew K. 
Published: December 2014

Abstract
In heavy oil reservoirs with bottom water drive, water coning severely hampers well productivity and oil recovery, due to excessive water production. Moreover, conventional enhancement techniques such as thermal and/or gravity-assisted production methods do not solve the problem of handling and processing large volumes of produced water. In this paper, we study feasibility of a new well completion and production technique using Multi-Lateral Water Loop (MLWL).
MLWL wells are multi-functional installations that feature three horizontal legs on the same vertical plane and at different depths. The top leg drains the oil payzone, the middle one controls water cresting by draining the aquifer beneath the oil-water contact (OWC), and the bottom leg injects the drained water deeper into the same aquifer. The top horizontal lateral provides maximum reservoir contact (MRC), low pressure drawdown and high production rate thus enhancing recovery. The middle lateral makes the oil production water-free, while the bottom lateral keeps the water underground without lifting it to the surface.
Using a reservoir simulation model of MLWL and a conventional horizontal well in a West African heavy oilfield, we study MLWL well design and operation that would make the technique superior to conventional horizontal well production in this oilfield. The results demonstrate the MLWL potential for increased production rate and ultimate oil recovery and the economic advantage of handling formation water in-situ. The study also explains how the MLWL system improves the recovery mechanism by mobilizing oil throughout the whole drainage area rather than in the well's vicinity. Furthermore, optimum operation conditions for water looping system are identified where economic limit is met and inverse coning avoided. The results show superiority of wells with downhole water drainage over conventional wells. Morover, the MLWL wells have additional advantage of prolonged economic life and, therefore, high profitability.