bluuebunny/crossref_metadata_2025_split huggingface dataset:
Planning and Implementing a SCAL Sample Selection Strategy for a Giant Carbonate Field Offshore Abu Dhabi, U.A.E.
Authors: Shebl Hesham , Tamimi Mohamed Al , Boyd Douglas , Muhairi Bashayer Al , Neyadi Abdulla Al , Jawhari Mohamed Al 
Published: December 2014

Abstract
Despite the importance of Special Core Analyses (SCAL) data to the construction of accurate reservoir simulation models, there is a lack of specific industrial guidelines for acquiring core and selecting representative plug samples, particularly for heterogeneous carbonate reservoirs. The aim of this paper is to share the strategy, practices and techniques Zakum Development Company (ZADCO) applied to obtain representative SCAL samples. There are two main aspects to the strategy; (1) coring and (2) plugging. The first stage is determining the parts of the reservoir to target for core acquisition. This requires an understanding of the distribution of static reservoir rock types (SRRT) in the reservoir and their importance to reservoir flow dynamics and fluid storage capacity. The second stage is designing a plugging program to identify reservoir rock types while maintaining the wettability of the samples intended for tests. For the second part, two adjacent sister plugs are acquired, one is a 1 inch diameter plug and the other is 1.5 inch diameter. The 1 inch diameter plug is used for static reservoir rock type (SRRT) identification using porosity, permeability, thin sections and high pressure mercury injection. The 1.5 inch diameter sister plug is preserved to maintain wettability and later used for SCAL measurements. Prior to selecting plug locations, a continuous, 0.5 mm resolution, 3D Computer Tomography scan of the 4 inch diameter whole core is examined. The scan has a high enough resolution that algal and rudist batches are visible. Accordingly, specific rock types are identified visually and targeted. After completion of SCAL measurements, the SCAL plug SRRT is confirmed, utilizing porosity / permeability measurements, thin section description and high pressure mercury injection. The majority of SCAL SRRTs matched the sister plug SRRTs, providing confidence in the technique.
Subsea Pipelines Integrity Management – ZADCO Approach
Authors: Trojette Mohamed Zouheir , Al Hammadi Mohamed , Al Alawi Faisal 
Published: December 2014

Abstract
Zakum Development Company, a major Oil and Gas company in the UAE, operates three offshore oil fields which are located at 65, 20 and 80 kms northwest of Abu Dhabi and are in shallow water with depth ranging from 6 m to 30 m.
ZADCO operates a large portfolio of subsea pipelines. Most of these pipelines have been in service for more than 30 years and corrosion is a major threat to the integrity of these lines. More over the increase in water cut, the decrease in the flow rate for some lines and crude composition changes mainly increase in H2S and CO2 levels are added challenges.
To mitigate these challenges, ZADCO has in place a series of barriers which include corrosion controls like chemical injection (corrosion inhibitors, biocides), maintenance pigging, etc.
Also ZADCO implements several corrosion monitoring activities like corrosion rate monitoring, intelligent pigging of the pipelines, verification of the In line Inspection results using Automated Ultrasonic inspection (Auto-UT) as well as fitness for service and remnant life assessment prior to repair and rehabilitation.
This paper presents ZADCO approach to manage the integrity of its subsea lines network and covers: –ZADCO Asset integrity management policy–Asset integrity Management System (AIMS)–Pipeline Integrity Management System Requirement (PIMS)–Intelligent Pigging–Corrosion Mapping (Auto Ultrasonic Verification)–Fitness for Service and Remnant life Assessment–Repair and rehabilitation plans–Concluding remarks
First-Ever Level 4 Multilateral Well in North Kuwait Successfully Completed, Improves Oil Production
Authors: Al-Khaldy Meshal , Dutta Abhijit , Goswami Bijan , Al-Rashidi Ali , Rondon Leonque , Warraky Mohamed , Samie Mohamed 
Published: December 2014

Abstract
Kuwait Oil Company (KOC) has recently drilled the first multilateral well in a North Kuwait field to improve oil production in productive layers subjected to water coning problems by increasing reservoir exposure using Level 4 multilateral technology. The multilateral well targeted the same sand in different directions with two laterals. Both of the laterals were drilled using rotary steerable drilling systems to reduce drilling time. The drilling process used a full suite of logging while drilling (LWD) tools, including azimuthal deep resistivity technologies, to ensure the well path is precisely geosteered within the reservoir boundaries and density/porosity tools in real-time, combined with specialized modeling software to position the well in the best possible reservoir.
Level 4 multilateral technology was selected after performing an extensive geological assessment and studying the challenges of exploiting oil in the target sand reservoir. The 12 1/4-in. main section was cased and cemented with 9 5/8-in. casing to the landing point; the 8 1/2-in. lateral-I was drilled and completed with 5 1/2-in. inflow control devices (ICDs). The sidetrack was performed by cutting a window from a specialized latch coupling in the 9 5/8-in. casing; the 8 1/2-in. section was drilled to the landing point, and the 7-in. liner was run and fully cemented. The 6 1/8-in. lateral-II was drilled and completed with 4 1/2-in. ICDs.
The fully cemented and cased junction or bifurcation should help achieve greater well integrity and prevent fluid migration from the adjacent area, while the specialized latch coupling should help ensure easy access to either of the laterals, as required. The ICD technology and swellable packers were selected to delay water breakthrough from an active aquifer.
This publication describes the application of multilateral and geosteering technologies, and analyzes the advantages and disadvantages of the first multilateral well drilled in North Kuwait that began with a campaign of higher order (Level 4) multilateral. The well is considered to be a pilot well to identify the feasibility of using multilateral technology as a production model to help enhance oil recovery and reduce drilling costs in the field by replacing the cost of drilling new wells.
Advanced Completion and Stimulation Design Model for Maximum Reservoir Contact Wells
Authors: Sau Rajes , Shuchart Chris , Grubert Marcel 
Published: December 2014

Abstract
This paper introduces a novel computational simulator for advanced completion and stimulation design of Maximum Reservoir Contact (MRC) wells. Using innovative computational algorithms, this simulator models numerous challenging physics of acid stimulation and transient injection of multiple fluids through openhole complex completions, e.g. Limited-Entry Liners (LEL) and Inflow Control Devices (ICD) in MRC wells. LEL hole or ICD nozzle diameter, hole distributions, and packers are explicitly modeled as part of the completion. The fast, robust simulator tracks concentrations and models flow of multiple fluids while explicitly accounting for completion and formation pressure drops along the lateral and transient reservoir dynamics. Fluid invasion and stimulation distribution (wormhole and skin) along the lateral are computed by the simulator which is coupled with a dynamic wormhole model.
A case history of the model application is presented. The model was used to design a limited-entry liner with 4 mm holes distributed non-uniformly among 12 compartments. The liner enabled successful high-rate bullhead stimulation of an 11,500-ft lateral, resulting in reduced cost, limited risk, and elimination of the need for coiled tubing. Model validation and calibration against the field data is discussed. Detailed evaluation of the well data suggests successful stimulation of the entire lateral and production uplift from every compartment.
The paper presents a novel, fast simulator to model transient fluid placement through complex completions in MRC wells. The capability to robustly model a complex completion in long openhole laterals has enabled the design of successful bullhead acid stimulation through a limited entry liner. Apart from acid stimulation design, the simulator also provides capabilities to model various well injection processes in sandstone and carbonate reservoir, such as scale squeezes, solvent treatments, and HF acid treatments.
Embracing Elevated Safety Tenets through Engineering Design
Authors: Katke Nitinkumar , Ghatge Vishwajit , Bokane Atul 
Published: December 2014

Abstract
This paper proposes adoption of a revised mindset with respect to safety by collaboratively implementing design and development. Given the nature of possible risks involved during operations, safety is a priority within the oil and gas industry. Transformation to an ideology of safety through engineering design requires a series of stages involving designing for safety at the nascent stage, prototyping with deliberately provided safety features, evolving the mindset by overcoming the resistance for change, and boosting the safety attitude, thus developed through continual practice.
A case study is presented in which field personnel were involved in the collaborative design process to seek input regarding the safety platform for trailers. To avoid trip hazards, landing steps, handrails, lock pins, and safety doors were designed to The Occupational Safety and Health Administration (OSHA) guidelines. Working at heights and ladder accessibility from a safety perspective is also addressed. Roller bearings have been devised to align the movement of platform in linear direction and to move the platform in open/work position. The position of the platform is locked by providing a locking nut. In a second case study related to offshore skids, numerous minor design changes were incorporated and computer simulated to help ensure the selection of a safe design. Fiber gratings were used on top so that slings would not fall down on equipment and the personnel working within the vicinity. Thirdly, a design process was developed wherein design teams provided input of various options for avoiding pinched fingers. This approach for an all-inclusive and collective discussion has helped to further evolve the outlook toward safety as a core value.
Infusing safety as a key element of the thought process creates immense value across industries in terms of applicability. A proper safety attitude can lead to significant returns in terms of reduced risk, workforce protection, enhanced quality, and improved overall economics. Addressing health, safety, and environment (HSE) risks, the safety platform and skids discussed here are now deployed in the field. The response from the end users is encouraging. Embracing safety focused thinking during engineering design helps provide an impetus toward bolstering safety culture.
Simulation of Residual oil Saturation in Near-miscible gas Flooding Through Saturation-dependent Tuning of the Equilibrium Constants
Authors: Patacchini Leonardo , Duchenne Sébastien , Bourgeois Marcel , Moncorgé Arthur , Pallotta Quentin 
Published: December 2014

Abstract
Conventional miscible or near-miscible gas flooding simulation often overestimates oil recovery, mostly because it does not capture a series of physical effects tending to limit interphase compositional exchanges. Those can be for instance microscopic bypassing of oil situated in dead-end pores or blocked by water films, as well as macroscopic bypassing due to sub-grid size heterogeneities or fingering.
We here present a new engineering solution to this problem in the near-miscible case, relying on our in-house research reservoir simulator (IHRRS). The principle is, while using a black-oil or an equation of state description, to dynamically decrease the K-value of heavy components and possibly increase the K-value of light components as the oil saturation reaches the desired residual limit; this enables changing the phase boundaries when needed while preserving the original fluid behavior during the initial production stages.
The benefits of the proposed method are demonstrated on a reservoir conditions tertiary gas injection experiment, performed in our laboratories, for which residual saturations as well as oil phase and individual components production rate have easily and successfully been history matched. Results are then compared to matches obtained using saturation exclusion and α-factors methods. As a proof of concept, suitability of the method to simulate incomplete revaporization of condensate during gas cycling is also illustrated, on the third SPE comparative solution project case.
The Longest Horizontal Well Drilled in The U.A.E., Geosteered in a Thin Calcareous Dolomite Sublayer
Authors: Abbas Nashat , Al Nokhatha Jamal , Farouz Ameer , Mohamed Emad , Abbas Syed Haidar , Hui Wang 
Published: December 2014

Abstract
September 2012, ZADCO drilled the longest well to date in the U.A.E. to test the productivity and injectivity of a low permeability, carbonate reservoir in a giant Middle East oil field. The extended reach well was drilled to a total measured depth of 24,390 ft., with a horizontal length of 11,015 ft.
The borehole target zone was a ~3.5 ft. thick calcareous dolomite sublayer sandwiched between upper and lower ~4 ft. thick limestones. The critical factors for success were: (1) LWD tools capable of differentiating calcareous dolomite from the nearby limestones; and (2) LWD sensors close to the bit as possible to enable prompt geosteering reactions to possible lateral facies changes. Challenges were: (1) the capability of the jackup rig to drill the required distance; (2) minimizing hole undulations; and (3) remain within the 3.5 ft. target zone. Concerns were raised about the use of nuclear chemical source density tools and the risk of a lost nuclear source in hole should the drill pipe become stuck. To address these concerns, the second half of the lateral section was steered without a chemical nuclear source in the downhole tool string.
A LWD formation pressure test tool was run post drilling to evaluate formation mobility. The result supported well placement in the higher permeability dolomite layer which was later validated by production and injection results.
This paper illustrates good geosteering practices in a challenging long horizontal well with carefully selected LWD program to achieve the target and reduce risks.
Wellbore Stability Analysis Using Acoustic Radial Profiles and an Elastoplastic Model
Authors: Hamid Osman , Rahim Zillur , Ba-wazir Omar A. 
Published: December 2014

Abstract
Wellbore instability during drilling, completion, and production is important and costly issue in many oil and gas fields. Field observations show that stress-related wellbore instability challenges are frequently encountered. Estimating stresses and mechanical properties is a key to the success of drilling, completion and production operations. Knowledge of accurate Unconfined Compressive Strength (UCS) is essential for understanding wellbore stability, perforation efficiency, and sanding tendency. UCS along the wellbore and perforation is a key input of failure criteria and can be best obtained from laboratory core testing that are mostly performed in the reservoir section. Cores from the overburden formation are rarely taken, although most wellbore stability related issues are encountered in this section of the well.
In this study, wellbore stability modeling was conducted using Finite Element Modeling (FEM) to predict induced stresses and yielded zone around the wellbore in the elastoplastic media. Elastoplastic models were used in conjunction with the Mohr-Coulomb and modified Lade yield criteria.
UCS is calculated by matching the resultant stresses around wellbore with dipole radial profiles from the Acoustic Scanning platform. The damage or yielded zone is interpreted by means of volumetric strain analysis. This damage provides an indication of the potential breakout that might occur during drilling, thereby giving an indication of the risks to wellbore instability.
This novel technique is applied to compute wellbore stability in the Khuff and pre-Khuff Formations in Saudi Arabia. The methodology can be applied to other locations using similar approach that combines acoustic radial response and FEM.
GASCO's Initiative for Emission Reduction in Oil & Gas Plants – Gas Turbine Replacement Project
Authors: Al Hammadi Nasser 
Published: December 2014

Abstract
The reduction of greenhouse gas emissions from oil and gas plants is without a doubt gaining widespread interest from leading companies around the world. Implementation of effective and best practice technologies to minimize greenhouse gas emission levels by the oil and gas industry will substantially lead to a better emission reduction practices and eventually increase the public confidence in this sector.
Many of the existing plants – especially those which were built 20 to 30 years ago – and are still in operation invariably have Gas Turbines mostly for power generation and process gas compression application. The exhaust from these turbines contributes substantially to increase emission levels.
Systematic approach is required to explore cost effective and practical alternatives to replace these Turbines with state of art non-emitting drives to reduce greenhouse gases which are emitted at present.
This paper presents GASCO's stepwise approach to determine most energy efficient & cost effective alternatives to replace emitting turbines as well as achieve a long-term reliable performance
This paper also presents a detailed implementation strategy from conceptualization to commissioning of new units and phasing out of old Turbines. It also describes critical reviews and decision making required at intermediate steps.
This paper, which details initiatives taken by GASCO to reduce emissions from the turbines and bringing additional advantages in form of improved reliability and increased longevity of the operating plants, will certainly provide insight to operators of similar plants to initiate measures for emission reduction and thus contribute substantially to protection of environment
Performance Review and Field Measurements of an EOR-WAG Project in Tight Oil Carbonate Reservoir – Abu Dhabi Onshore Field Experience
Authors: Figuera Luis , Al-Hammadi Khaled , Bin-Amro Khaled , Al-Aryani Fatema 
Published: December 2014

Abstract
A Water-Alternating-Gas (WAG) scheme is a proven enhanced oil recovery (EOR) method. The first WAG project was reported in 1957 and until today more than sixty (60) field experiences can be found in the literature. Most of the published experiences report 5-10% additional oil recovery over waterflood. WAG injection can lead to improved oil recovery by combining better mobility control, improved microscopic displacement, and better sweep efficiency.
This study presents a recent field experience where a miscible WAG injection has been designed and implemented with the objective of enhancing oil recovery in a heterogeneous, low dipping, and tight carbonate reservoir. The project has been performed on close-spaced slanted wells and utilizes rich hydrocarbon gas. Since the beginning of the injection, an integrated surveillance program has been applied to determine whether the miscible flood is working efficiently. This program involves observation wells, time-lapse saturation logging, well testing, tracer injection, and i-field technology along with numerical simulation.
This paper presents a review of the main findings, issues and lessons learned during eight (8) years of EOR-WAG injection. The paper discusses the project design, the integrated surveillance program and the WAG mechanisms to enhance oil recovery. It also summarizes worldwide WAG experiences based on published field observations.
Pushing the Limits of Distributed Temperature Survey Analysis in Mega-Reach Power Water Injectors
Authors: Dhufairi Mubarak , Yateem Karam , Duthie Laurie , Kilany Khaled , Elsherif Tamer , Ahmed Ramy 
Published: December 2014

Abstract
Increases in well complexity and stimulation challenges have led to more complicated stimulations. The challenge that consistently arises after conceptually designing the treatment is how to determine the zonal coverage and evaluate the stimulation, especially in extended reach wells in carbonate reservoirs. Significant effort has been spent on using modern technologies to qualitatively evaluate zonal coverage and estimate the skin factor evolvement after the treatment. No work has yet answered the following question: How does matrix acidizing alter near-wellbore permeability and affect the zonation of the wellbore when treating carbonate reservoirs?
In long horizontal wells that are drilled in carbonate formations, it is believed that wormholing significantly alters the near-wellbore apparent permeability. Nevertheless, methods to estimate the change in permeability resulting from a matrix treatment are not known, and usually the change is accounted for in simulators by assigning a very low skin value. Other work conducted in carbonate reservoirs using pressure transient analysis (PTA) techniques has shown that applying a change in permeability is necessary to obtain a type-curve match.
This paper presents an innovative workflow and algorithm to estimate the changes in the critical matrix rock properties and how to incorporate these changes into further simulation. The algorithm integrates the while drilling mobility data, open hole porosity logs, pressure transient data, distributed temperature survey data, and production logging data to verify the accuracy of the model by using the flow rate as the control parameter for iterations.
A case study shows how we could derive a flow profile for the pre-stimulation stage, optimize matrix stimulation treatments in real time according to the formation response and diversion efficiency, define reservoir zones that are contributing to flow before and after the treatment, and finally, estimate new values of permeability and skin to be utilized in post-treatment reservoir simulations.