bluuebunny/crossref_metadata_2025_split huggingface dataset:
Success of Rigless Multi-Stage Selective Stimulation in Super-Giant Tight Reservoirs - Case History from UAE
Authors: Fahim Mohamed Abdullah , Abdullah Ali , Abdallah Dalia , ElBarbary Abdalla , Daghmouni Hamdi Bouali , Waheed Syed Arshad , Tawakol Moataz 
Published: December 2014

Abstract:
Enhancing hydrocarbon recovery is the ultimate goal in the oil and gas business; nowadays there are many technologies that can be applied effectively to reach that goal; Maximum reservoir contact (MRC) wells, Under-balanced drilling (UBD), Multi-laterals (ML), fishbone. etc. However, still the preferable, economical option is to improve the well production by stimulation which is applied easily and riglessly in existing or newly drilled wells.
In many horizontal or long pay zone wells; the optimum results cannot be achieved through conventional stimulation techniques because it is difficult to ensure even stimulation fluid distribution (i.e. acid in the case of carbonate stimulation) across the entire lateral hole unless some sort of selective stimulation can be performed. This is a prerequisite for successful result. It becomes more challenging in heterogeneous open hole completions which have natural fractures. Even more challenging is trying to achieve selective stimulation in such complex geological environment when specific reservoir compartments need to be treated specifically.
A tight gas carbonate reservoir with no oil rim in a super-giant onshore gas field in Abu Dhabi was particularly targeted for stimulation during a field review to increase field production. Conventional stimulation treatments performed to restore well productivity resulted in rapid performance decline as a result of undesired worm-holing throughout the existing bore hole and uneven flow contributions. PLTs’ were run in three wells to understand the well productivity. The results showed that most of the gas production (approximately 95%) was from upper zones while the remaining production came from the lower zones which were of poor reservoir quality. It became necessary to look at selective fracturing stimulation techniques that could be applied riglessly and allow contribution from the non-producing zones.
This paper describes a unique engineering approach, the Hydrajet Fracturing (HJF) technique that was successfully executed for this purpose. The objective was to apply an economically feasible, rigless, selective fracturing technique with efficient placement approach that would lead to proper reservoir drainage. Pin-point stimulation at selected points was considered an important factor for the development of this field. After the unique stimulation treatment, a new technology based on spectral noise logging and temperature distribution survey was used to evaluate the contribution of the targeted fractured zones in conjunction with pressure buildup well test analysis. Several lessons were learnt from the first use of this technology and some interesting conclusions were reached from these investigations.
First Full Field Application of Distance Separated Simultaneous Shooting to 3D OBC Survey Offshore Abu Dhabi, UAE
Authors: Nakayama Shotaro , Al-Mansouri Khalfan Hassan , Benson Mark Allen , Mercado Gary , Belaid Kamal 
Published: December 2014

Abstract
ADMA-OPCO undertook a large 3D-4C OBC survey over an oil and gas field offshore Abu Dhabi, UAE. The survey was designed to acquire high fold datasets (400 at 4,000 m inline and crossline offsets with 12.5 m × 12.5 m bin size) along with having wide azimuth sampling for each offset range. The survey utilizes simultaneous source technique so-called DS3 (distance separated simultaneous shooting) to enhance survey productivity and minimize HSE exposures in the field.
The DS3 employs two source-vessels traveling at a distance and firing simultaneously so that two wave fields can be recorded with minimal seismic interferences. However, this technique still has potential to introduce certain level of seismic interference from the other sources in an OBC survey. Thus, optimum spatial and temporal separations between two source-vessels are analysed to minimize seismic interferences. Field tests are then performed with the main objective of confirmation of seismic interference patterns and their significances prior to field wide application.
With DS3, the survey achieve remarkable enhancement of survey productivity (i.e., a peak acquisition rate of more than 12,000 SPs / day) as compared to conventional single source-vessel configuration. DS3 along with proper spatial and temporal source-vessel separations, based on analysis of seismic interference patterns and field tests, enable recorded data to be handled as non-simultaneous source survey. Consequently, DS3 does not require any specific algorithms for de-blending so processing of DS3 datasets is fairly simple and straightforward.
In this paper, we introduce first field wide 3D OBC survey incorporating DS3 technique along with analysis on seismic interference wave fields and field tests which are performed prior to 3D survey. Additionally, we show some of the operational challenges associated with DS3 for OBC surveys.
Microbial-Induced Oil Viscosity Reduction by Selective Degradation of Long-Chain Alkanes
Authors: Sugai Yuichi , Komatsu Keita , Sasaki Kyuro , Mogensen Kristian , Bennetzen Martin Vad 
Published: December 2014

Abstract
Application of a thermophilic anaerobic bacterium which degrades long-chain alkanes of crude oil preferentially and induces oil viscosity reduction to MEOR in our target oilfield was evaluated in this study. Although the salinity of formation-water in our target reservoir is approximately 10 % which is considerably higher than the optimum salinity for the bacterium, the bacterium can grow well and induce oil viscosity reduction in the formation-water which was diluted with sea-water whose salinity was approximately 4 % and contained yeast extract as a nitrogen source. Oil viscosity was reduced to 70 percent of its original viscosity after two-week incubation of the bacterium in the culture medium consisting of sea-water supplemented with 1.0 g/L of yeast extract.
The performance of MEOR using this bacterium was evaluated by numerical simulation using two dimensional oil-water two-phase flow model. This model consists of 6 compositions: degraded oil, undegraded oil, brine, bacterium, sodium chloride and yeast extract. Undegraded oil and yeast extract are carbon source and nitrogen source for the bacterial growth respectively. Growth rate of the bacterium is calculated by Monod equation depending on the variables of the concentration of yeast extract and sodium chloride. Conversion of undegraded oil into degraded oil is depended on the proliferation of the bacterium. Growth of the bacterium is stopped by deficiency of either yeast extract or undegraded oil. Oil viscosity is reduced as the percentage of degraded oil in oil phase increases. Residual oil saturation is improved by oil viscosity reduction and enhancement of oil recovery can be obtained.
According to the numerical experiments, growth of the bacterium and oil viscosity reduction were found only around the injection well because the bacterium consumed whole yeast extract around there. Recovery factor therefore can be increased by increase of injection volume of yeast extract. As a result, enhancement of oil recovery reached to 5 % by 1.0 pore volume injection of sea-water containing the bacterium and 1.0 g/L of yeast extract. 100 bbl of oil was recovered additionally by using 1.0 tons of yeast extract in that case.
The Future Leaders Conference – An Effective Tool for Nurturing Young Leaders for Sustainable Growth
Authors: Al Mazroui Ali , Al Shamlan Omar Salem , Farea Seena M. , Al Ghaithi Sultan , Jamaluddin Shaju 
Published: December 2014

Abstract
The emergence of U.A.E as a knowledge society, whirling with high potential transformation, has created a huge demand for leaders of high caliber. Under the vast support of Abu Dhabi National Oil Company (ADNOC), Abu Dhabi Marine Operating Company (ADMA-OPCO) stepped ahead and introduced the concept of ‘Future Leaders’ Conference', (FLC) in 2006, with the objective of empowering Young Professionals of UAE to be Future Leaders with guaranteed skills, matching the needs of a dynamic economy.
The FLC, a powerful two-day learning event with its novel objectives, is a first of its kind in the Oil Industry of UAE. Conducted every year, FLC is attended by the ADMA-OPCO Senior Management, representatives from ADNOC sister-companies and industry peers from within and outside UAE. Delegates to the event are star performers from the Competency Assurance Management System (CAMS), a scientific and systematic development scheme, spearheaded by ADNOC. The ‘power packed’ event, showcasing role models through well planned sessions and an exhibition, provides ample opportunity for industry focused personal development. The entire event revolves around a central theme selected for each year, like – ‘Team Work’, ‘Collaboration’, ‘Accountability’, ‘Journey to Excellence’, ‘Strategy to Success’, all cascaded from Leadership Conferences attended by middle and senior level managers of ADMA-OPCO. More importantly, the FLC is aligned with Objective No. 25 of ‘The Abu Dhabi Economic Vision 2030’, nurturing the Nationals to meet the challenges of a vibrant economy.
The feedback from the Young Professionals on the impact of FLC is highly positive and encouraging. One of the quantifiable impacts of FLC is- ‘Zero Percent Delay’ in integrating the Young Professionals into target positions, through well-defined developmental programs. The benefits of FLC for the Nationals include valuable insights into aspects like the culture and value system of ADMA-OPCO, synergy between various stakeholders and business elements, professional networks for sharing knowledge, facilitating a new outlook for their career and future.
Over the years, FLC has evolved into a very effective tool in empowering the Young Professional as Future Leaders for sustainable growth and to face business challenges in the Oil & Gas industry of fast growing UAE.
Making Un-Drillable HPHT Well Drillable using Mud Cap Drilling
Authors: Al-Awadhi Farhaad Khaled , Al Ameri Fahed Salem , Kikuchi Shuichi , A Afify Hassan Alhussieny 
Published: December 2014

Abstract
The operator of Well-A, a HPHT gas well in offshore Abu Dhabi faced a difficulty to drill ahead in a high-pressure fractured gas reservoir of "K" formation due to severe lost circulation followed by gas influx into the wellbore, namely loss/kick incident. The sudden and huge amount of mud losses at the bottom part of the reservoir led to gas flowing from the upper one observing a rapid pressure hump in the annulus between the wellbore and drill pipe. The operator then experienced complex well control situations including the burning of the entry gas to the atmosphere. The hole was finally plugged for the sidetracking due to a sticking occasion during the remedial action for the losses.
The integrated drilling team recognized a little or no success of drilling to the intended well total depth in case of continuously using conventional drilling methods, began to pursue alternatives and soon initiated Mud Cap Drilling, one of the MPD methods at the multiply fractured reservoir while drilling the 8–3/8″ sidetracked hole. The application of the Mud Cap Drilling permitted efficient drilling resulting in 27 days' time saving compared with the planned duration. Furthermore, it completely prevented the well from flowing and could make the un-drillable well drillable.
This successful drilling of the problematic gas reservoir using Mud Cap Drilling in the Well A has made a further encouragement of drilling HPHT gas exploration wells, which contain a lot of uncertainties in the formation pore pressure and fracture gradient profiles. The MPD as a flow control and pressure steering tool will prevent the forthcoming HPHT gas exploration wells from several drilling hazards resulting in NPT such as kick control, losses, wellbore instability, and differential sticking, slow ROP, etc. Moreover, it will allow minimizing the number of casing to be run and reducing formation damage to the gas reservoir.
This paper describes the positive impacts of the application using PMCD equipment, lessons learned from the implementation and areas for the further improvement of MPD application in future.
First Wireline and Elevated Pressure Coring in UAE - Saved 30% of Coring Time for Shallow Reservoirs & Delivered Realistic Fluids and Gas Saturations
Authors: Ali M. , Hegazy G. M. , Aftab M. N. , Negm A. M. , Syed A. A. , Anis A. , Schipper B. 
Published: December 2014

Abstract
For many years, coring operations suffered from frequent jamming due to abrupt changes in lithology and rock properties. Core jamming leads to potential core damage, excessive number of trips, longer operation time and thus higher cost. Frequent and abrupt lithology and rock property changes are natural occurring phenomena. To mitigate the implications of core jamming, a robust coring technology platform has been deployed, which allows alternating between coring, pressure coring and drilling without pulling out the drillstring. The applied wireline-retrievable coring technology offers an efficient and cost effective way to trip-out large diameter core, thus achieving high recoveries of high quality cores. It also allows the Operator to almost decide real-time to drill ahead or to retrieve additional cores without performing additional trips. The coring/pressure-coring/drilling assembly is designed in such a way that it is efficient to switch from coring to pressure-coring or to drilling modes and vice versa, without tripping the drill pipes. By eliminating trips, this technology is extremely cost effective for multiple coring targets, especially when incorporating inter-drilling sections. The wireline-retrievable coring technology was also successfully applied to obtain pressure core, deploying breakthrough technology for the first time in the Middle East that retains the hydrocarbon content in its native state, with no lost gas, until core retrieval and evaluation on surface.
This paper describes a case history of the first deployment of the wireline-retrievable coring/pressure-coring in the UAE and the Middle East, while saving significant rig time compared to conventional coring.
A Record Breaking Achievement Confirming Assets Quality & Reliability The First Oil & Gas Company to Obtain the New International Standard ISO55001:2014 Certification.
Authors: Daoud Mohamed , Mohamed Alaa , Fawzy Mohamed , Khalifa Fatima , Helmy Aymen , Badeyab Ahmed 
Published: December 2014

Abstract
Today's economy is driving the need for smarter asset management with increased expectations from companies, regulators, and shareholders at a time when assets are becoming much more interconnected, instrumented, and intelligent.
ISO 55000 is the first worldwide attempt to capture the generically applicable ‘must do’ items for the asset management that provides significant opportunities to refine asset owner and service provider relationships, governance and regulatory frameworks and insurance, customer relations and other stakeholder confidence.
ADCO has invest a lot in developing, implementing and maintaining systems to manage its assets, that crowned by attainment of BSI PAS-55 certification on 2012 as the 1st Oil Company among GCC, complimented by acquiring ISO-55001 certification on 2014 as a part of its vision to provide the required level of asset management sustainability to its Facility Management.
The purpose of this paper is to share ADCO's experience gained during its journey for getting ISO-55001 certification for assets management system.
Accounting for Multi-scale Permeability Systems in Reservoir Models of a Giant Offshore Oil field, Abu Dhabi – Balancing Matrix Versus Excess Permeability and its Impact on Reservoir Performance
Authors: Skene Kenneth I. , Yamamoto Kazuyuki , Brantferger Ken , Quintero Maria , Kompanik Gary , Ottinger Gary , Manal Al Harbi 
Published: December 2014

Abstract
It is well known that the permeability of porous media represents a first order control on fluid flow in hydrocarbon reservoirs and that the magnitude of the permeability often depends on the rock volume under consideration. Core plug permeability does not necessarily equal whole core permeability and permeability from core may not necessarily reflect well test permeability. Each of these disparate data sources measures permeability at a particular scale. For the purposes of reservoir modelling, the permeability systems characterizing a giant offshore oil field have been broadly categorized as either matrix permeability or excess permeability. Matrix permeability further subdivides into two categories based on the abundance and type of microporosity. Excess permeability subdivides into three sub-categories depending whether it is the result of depositional processes emplacing anomalously high permeability storm beds (HKS or high permeability streaks), diagenetic processes creating dissolution enhancement of permeability, or fractures. Although not all these permeability systems are active in any reservoir interval, each reservoir interval possesses at least two if not three of these systems. The multi-scale nature of permeability arises because of 1) differences in the spatial extent of these permeability systems and 2) permeability contrasts between the systems.
Several techniques have been developed and will be explored in this paper that attempt to account for the influence of multi-scale permeability systems on reservoir performance behaviour. In what might be the simplest case, the mixture of permeability systems includes only matrix permeability without significant microporosity and excess permeability resulting from HKS. In this case, matrix permeability was modelled independently of excess permeability creating significant short-range permeability contrasts that better predicted reservoir pressures and water movement in the reservoir during history – matching. In another case with the same type of matrix permeability, the excess permeability represents the contributions from a mixture of fractures and HKS. In this case, matrix permeability was also modelled independently of excess permeability. Estimates of the relative contributions of HKS and fractures to excess permeability were tested as a history-matching parameter. Ultimately, this approach to characterizing permeability attempts to capture some of the rudimentary aspects of a dual permeability model without incurring the associated computational expense.
Mercury Removal Units Operation at Front-end Location
Authors: JUBIN Clotilde , DUCREUX Olivier 
Published: December 2014

Abstract
Mercury is present as elemental mercury in natural gas reservoirs and has to be removed in the natural gas processing plants to protect health, environment and equipment. The mercury removal options are mainly non-regenerative products. The adsorption mechanism is a chemical reaction between mercury and the sulfur of the active phase to form non-hazardous and very stable cinnabar phase.
The trend is to implement mercury removal vessels the closest to the production wells to minimize mercury contaminations in natural gas plants. This up-front location implies adsorbents able to remove mercury from high operating pressure water saturated natural gas. Metal sulphide active phase adsorbents have been developed for this purpose.
This paper will present examples of commercial application with existing mercury removal solutions to illustrate the benefits available from use of the new technology focused on engineered alumina based products. A case study based on performances comparison with different solutions at up-front locations will be presented.
Decommissioning Process for Subsea Pipelines
Authors: Philip N. S. , Wilde S. , Arshad R. , Washash I. , Al-Sayed T. A. 
Published: December 2014

Abstract
The method and standards employed in the decommissioning and abandonment of offshore oil and gas pipeline assets at the end of their useful life are determined by a framework of national legislation, international protocols and treaties, and corporate governance standards. The framework will impose legal obligations upon operators to ensure marine environments are protected. Fines and penalties may be imposed if the asset owner fails to meet these requirements.
A regulatory, or any similar, body will not prescribe a detailed planning process. Nonetheless, the body will usually expect to approve details from an asset owner on how the decommissioned activities will be planned, executed, and monitored within the regulatory framework. Additional requirements from other stakeholders within an operating company and corporate governance standards will also impose obligations on the decommissioning project.
This paper describes an overview of a decommissioning plan which could be used to meet typical obligations required by regulatory frameworks. It will cover: Interpretation of national regulations and international treaties.Identification of technically credible options to decommission the asset.Identification of data gathering requirements. Environmental data is particularly important and in some cases needs to be collected over an extended period of time leading up to decommissioning.Evaluation of the options based on legislation, environmental impact, safety, technical feasibility, and cost.Development of detailed methodologies.Estimation of costs.Definition of ongoing obligations in terms of surveillance and maintenance requirements.Preparation of scopes of work for tendering to contractors, including supporting procedures and work packs.
A Fast Parallel Coupled Hydraulic Fracture Simulator
Authors: Shetty Dinesh , Lin Avi 
Published: December 2014

Abstract
The multiphysics of hydraulic fracturing unconventional reservoirs is complicated, involving large, dynamic, and complex-shaped fracture networks composed of natural, hydraulic, and induced fractures, multiphase flow, solid-fluid interaction, and fracture-reservoir coupling, all of which make numerical simulation computationally prohibitive. Thus, innovative and efficient algorithms that are accurate, stable, and scalable to exploit modern hardware have become imperative. In this paper, a novel multigrid-based computational approach for hydraulic fracturing simulation is proposed and analyzed. It is composed of four grids; namely, the junction grid, the fracture grid, the rock block grid, and the reservoir grid, which are listed in hierarchical order. The reservoir is represented in the most inner level through a set of one-dimensional (1D) domains. In the next level, the fractures are represented through a collection of connected 1D grids. The fracture and the reservoir coupling lead to a pseudo-two-dimensional (2D) (fish-bone like) structure. The rock block dynamics are simulated on a 2D grid. On the top of the hierarchy, a 2D junction grid interacts directly with the fracture and rock grids. In this multigrid approach, the reservoir lines are first eliminated using fast parallel Cholesky decomposition. This is followed by an elimination of fractures using parallel Gauss elimination. Simultaneously, the rock blocks are also solved in parallel. This computational approach reduces the original large problem into a condensed small problem formulated only in terms of the junction variables. The resulting small sparse junction system is efficiently solved to obtain the solution on the junction grid. Then, this solution is propagated to the fractures through a primary prolongation operation. Finally, the solution for the reservoir grid is reconstructed from the fracture grid through a secondary prolongation operation. The capability of the algorithms is illustrated through actual simulations.