bluuebunny/crossref_metadata_2025_split huggingface dataset:
Maintaining Seal Integrity During Waterflooding in Shallow Depleted Heavy-Oil Sands: Implications to Geomechanical Model
Authors: Ahmed Khalid , Zhang Ian , Schutjens Peter , Benham Philip , Saika Pabitra , Mirhasanov Ramil , Al-Rabah Abdullah , Reijnders Gert-Jan , Warrlich Georg 
Published: December 2018

Abstract
Cap rock integrity assessment is one of the corner stones for heavy oil field development where thermal, water flooding, or other Enhanced Oil Recovery (EOR) related fluid injection operation is involved. In this paper, we present our recent work related to cap rock in a heavy oil field in Northern Kuwait. The cap rock in our field is unique in many aspects compared to other heavy oil fields around the world, in that it is very shallow in burial depth, highly unconsolidated with high porosity and permeability and very ductile in terms of geomechanical properties. Furthermore, there are multiple pay reservoirs separated by different mudstone layers, so the term of cap rock becomes somewhat vague and complicated by itself. The unique properties of the cap rock in our field call for unique core analysis approaches and put up exciting challenges to petrophysical data acquisition and interpretation. A special core analysis approach has been adopted to provide mudstone porosity and permeability that is different from either the Gas Research Institute (GRI) shale analysis or the more conventional routine core analysis suitable for clastic rocks. Integrated study has been performed to understand these special attributes of the mudstones in this field, using core analysis, downhole wireline and surface mini frac measurements, which are all used as inputs into geomechanical model initiation.
Based on integrated study, we have established the fracture gradient of different layers of mudstone intervals, gain initial understanding of the rock property of mudstones in this field, and identified data and information gaps that need to be closed by further data collection and study. In the end, we have made recommendations on future mini frac data collection and core analyses for shallow unconsolidated ductile mudstones.
Understanding and Parameterization of Greater Burgan Fluid Spatial Variation Using an Extensive PVT Data Base
Authors: Ortegon Luis Rodrigo , Al-Shammari Nouf Abdullah , Al-Qattan Abrar , Al-Samhan Amina , Al-Enizi Nawaf Khalaf , Duvivier Giles , Brown Richard C. , Perez Godofredo , Ritchie Sarah 
Published: December 2018

Executive Summary
Fluid characterization and mapping in the Greater Burgan field was performed using an extensive database of PVT analysis reports. This enabled an enhanced understanding of the distribution of fluids, in which a lateral compositional gradient was discovered.
Summary information of 381 samples that had been acquired from 1938 to 2017 was gathered and plotted against both true vertical depth subsea (TVDSS) and spatial directions (northing and easting). Correlations of average fluid characteristics of all these samples against TVDSS and the direction in 15° north-east was determined. The API gravity, oil viscosity and solution gas to oil ratio were parameterised as a function of horizontal direction and depth. The saturation pressure was modelled using a correlation, being a function of the other variables modelled in space. Over 30 correlations published in the literature were ranked, and the best-fitting correlation was selected to predict the saturation pressure distribution spatially. All these properties were mapped by formation.
This is the first study in which the existence of this lateral gradient is fully described. This work is being used as a reservoir management tool to predict zones close to or below the saturation pressure and reduce the production offtake from those zones and to develop an appropriate sampling plan. This work has also help manage access to the heavy oil zones.
Integrated Study for Well Productivity Enhancement in a Heavy Oil Reservoir in Northern Kuwait
Authors: Kharghoria Arun , Ahmad Khalid , Al-Rabah Abdullah Abdul , Guha Kaustubh , Kalia Devesh , Montero Jacobo 
Published: December 2018

Abstract
Focused well reviews were carried out to identify productivity enhancement opportunities in a heavy oil reservoir in Northern Kuwait. In an integrated effort, involving multi-disciplinary and cross-functional teamwork, well and reservoir management opportunities were assessed. The goal was to recommend well restoration and optimization opportunities for short, medium and long-term implementation, thereby creating a business impact.
The process involved an in-depth comprehensive review of 59 wells. Available completion, production and pressure build-up data were tuned to analytical well models to assess individual well. Inflow performance analyses and the sensitivity check were done for drainage volume. Based on the difference between actual well performance and its estimated potential, production enhancement opportunities for the under-performing wells were estimated with proper engineering judgement.
Initial Productivity Indices (PI) were found to be consistently higher than actual well performance during the production phase, potentially due to initial flush production and short duration of the initial tests. Design of facilities, well configurations (deviated wells) and sand production were also investigated and found to have some degree of impact on well performances. Out of 59 wells reviewed, opportunities were identified for 44 wells (~75%). Out of these, 26 wells were identified for productivity enhancements methods and water shut-off/management (18 wells). Once recommendations are implemented, oil production is expected to increase by 20%.
Results obtained from the study indicates that the approach of suitable inflow management is a critical aspect to the heavy oil recovery project. This approach could be applied to other heavy oil projects with practical challenges of oil production with managed gas and water productions to maximize recovery.
Optimizing Training Paths in the Heavy Oil Realm: Insights Developed in KOC
Authors: Capello Maria Angela , Benham Philip , Warrlich Georg , Sousa Maria J. , Nassef Mostafa , Cheers Michael 
Published: December 2018

Abstract
Developing the necessary skills in the oil and gas workforce has always been a challenge for operating companies, as each individual needs not only knowledge in their specific discipline but also sufficient understanding of the interfaces to other parts of the business. The challenge is higher for specialized areas of application, like Heavy Oil. This paper will present our insights and learnings in the process of shaping skilled profiles needed to handle heavy oil developments, grounded on our experience in Kuwait Oil Company (KOC), with a focus on subsurface profiles.
To further support the development of its heavy oil resources, KOC signed a 10-year Enhanced Technical Services Agreement (ETSA) with Shell in December 2016, in which a key driver is the enhancement of KOC staff technical competencies. Within this framework, KOC and Shell jointly created a capabilities-development program for Heavy Oil staff, encompassing discipline-driven coaching, on-the-job training, attachments, mini-learnings, and customized courses, constituting a blended-learning approach.
Heavy Oil developments and operations require integration of information, knowledge and experience from the very early phases of the field development, due to the high cost per barrel that challenges profitability. Every optimization counts. In addition, there are specific skills inherent to heavy oil, like steam injection expertise, cap rock characterization, modeling/management of viscosity changes, besides processing and transportation.
After the culmination of the first year of the ETSA, opportunities to accelerate the uplift the efficacy of the training plans for heavy Oil skills were identified: Cross-discipline training, to enhance the integrated approach to studies and operationsMore operational and hands-on training formats needed in the blended training frameworksAssessment processes, pre- and post-learning events, to measure the value of trainingStrategic career planning as a planning requisite for the optimization of trainingSoft skills training, to endow the creation of enriching teamwork, beyond corporate cultural nuances.
A selected example will exemplify how the collaboration efforts IOC-KOC for integration were successful, exposing Reservoir Engineers to an integrated core and field-based seminar that was shifted from a pure geological focus to address multidisciplinary topics such as reservoir modeling, steam conformance, reservoir heterogeneity and integrated analysis of subsurface-surface interdependence.
The learnings derived from the first year of exchange and collaboration between an NOC and an IOC will be useful for similar cases in the world, to augment the specialized skills and core expertise in the oil and gas workforce.
From Exploration to Production in Record Time: A Case Study of Lower Fars Heavy Oil Reservoir in Umm Niqqa Field, Kuwait
Authors: Sajer Abdulaziz , Al-Bader Haifa , Al-Rabah Abdullah , Singh Sunil , Harami Khalid , Dillabough Garahm , Al-Ajmi Afrah , Al-Ibrahim Abdullah , Ayyavoo Mani Maran , Al-Ateeq Abdullah , BoSalhah Ammar , Dashti Jalal , Al-Qattan Faisal , Al-Houti Shoroq , Mushnuri Sudhakar , William Awad , Arguello Luis , Sangani Pratik , Chakravorty Sandeep , Franco Francy , Sahmkow Roberto 
Published: December 2018

Abstract
Conventionally discovery to development of a heavy oil reservoir takes very long (Minimum 10-15years). However, significant volatility in the oil prices have required more collaborative workflows and strategies from operators and service companies to optimize cost and maximize efficiency and innovation. We present here a joint service integrated model between an NOC and a service company which was used in the fast track development of an unconventional heavy oil reservoir and resulted in discovery to production in record time.
A conceptual field development plan was put in place for fast track development of the Lower Fars reservoir in the Umm Niqqa field after drilling and testing 26 exploration wells. The plan consisted of drilling and completing over 80 wells in conjunction with the construction and commissioning of an early production facility (EPF) to handle the sour heavy crude. Given the brief time and the unconventional nature of the reservoir, significant challenges were faced during the execution phase. To address the challenges, an integrated workflow was put in place combining multiple disciplines. The entire project required seamless integration between drilling, characterization, production and surface facility teams for flawless execution. The collaboration resulted in successfully drilling and completing all planned wells in less than 1 year.
This paper describes the tasks performed during the project for successful execution. It was initiated by a robust assessment of the discovery in terms of OIIP and type of hydrocarbon. It further describes the construction of a fit for purpose field development plan. During the execution phase we explain the challenges faced while drilling deviated wells in soft unconsolidated reservoirs with extremely shallow kick off points. The challenges in logging and evaluating deviated wells to optimize completion strategy are also described. The optimization of testing, completions and artificial lift workflows played a significant role is assessing the dynamic behavior of these reservoirs. The workflows in conjunction with continuous production monitoring and workover planning allowed the minimization of non-productive time (NPT). We further highlight the surface facility designed for such heavy sour crude and the recommendation for future development.
Feasibility of Multi-Physics Reservoir Monitoring for Heavy Oil
Authors: Passalacqua Herminio , Davydycheva Sonya , Strack Kurt 
Published: December 2018

Abstract
A new microseismic-electromagnetic (EM) acquisition system for reservoir monitoring includes surface and borehole hardware, processing software and interpretation methodology. For heavy oil reservoirs it allows mapping of steam/water flood fronts and surveillance of cap-rock integrity. The new array acquisition architecture combines novel technologies which reduces operational cost, due to unlimited channels capability: EM and microseismic acquisition is in the same receiver node to optimize the synergy between the methods.
While microseismic channels address seal integrity information, EM data are used to track fluids, due to their high sensitivity to the fluid resistivity. The fluid resistivity drops strongly with mobility increase and pore size variation. Dense data further reduce the cost per receiver in a surface location. EM channels provide three-component (3C) electric and 3C magnetic data acquired on the surface and in shallow vertical boreholes. For later versions and deeper reservoirs deep wireline receiver with through casing measurement capabilities are planned. We include in the system an independent physics verification measurement using a differential approach to the surface data called focused source EM (FSEM) with practically little cost.
Carrying out feasibility for each reservoir is key to control risk and cost. The feasibility includes 3D EM modeling, which allows integrating typically complex nature of the reservoir, and on-site EM noise test to tie 3D modeling to actual measured voltages.
3D modeling feasibility for a heavy oil reservoir proves the methodology to monitor the boundaries of the steam flood with accuracy and with high fidelity. Above the edges of the flooded (higher-temperature – lower-resistivity) area the results predict time-lapse EM anomaly exceeding 500%.
The entire system is coupled with processing and 3D modeling/inversion software, significantly streamlining the workflow for the different methods.
The system is capable of measuring and integrating the 3C of the electric field and 3C of the magnetic field in order to map the steam front and at the same time measuring microseismic occurrences in order to monitor seal stability. Channels capability of the system is practically unlimited allowing a denser coverage of the area in order to increase resolution and improve inversion.
Successful Installation of Stand Alone Screen in Challenging Environment in Umm Niqa Field
Authors: Zeidan Amr , Al-Bader Haifa , Pandey H Chandra , Al-Ibrahim Abdullah , Ayyavoo Mani , Al-Ateeq Abdullah , AL-Kandary Esraa , Erhamah Abdulaziz , Bosilca Daniel 
Published: December 2018

Abstract

Objectives/Scope
In 2014, number of exploratory wells were drilled and tested in Umm Niqa (UN) Field located in north Kuwait NE which approved a new discovery in Lower Fars (LF) reservoir.
LF is unconsolidated, sub –hydrostatic- sand stone reservoir with highly sour and moderate corrosive environment (H2S 8% and CO2 4%). Subsequently additional wells were drilled to evaluate the production potential of UN field. With rig on location UN wells are completed with test (Progressive Cavity Pump) PCP and tested. During the initial testing period the PCP is run at different speeds to evaluate the well productivity, water cut, and determine sand-free draw down to enable selection of suitable completion PCP for production.

Methods, Procedures, Process
Well UN-X is one of the developed wells which is perforated in LF sand in overbalanced condition using 4-1/2" (High Shot Density) HSD guns with 0.83" entrance hole diameter at 12 shoots per foot.
During initial testing with test PCP, the pump tripped due to high torque because of sand production (up to 60%). Five runs were performed to clean out the wellbore and repeated test PCP runs failed due to high sand production.
Coordination between FDHO (Field Development Heavy Oil) and Discovery Promotion Team was conducted to perform quick sand analysis to LF sands from offset sand distribution since subject well has no available sieve analysis. Based on the outcome of sieve analysis, decision was made to utilize one of the available SAS (Stand Alone Screen) designed for LF sand in another field to control sand production. It was agreed by both teams to install SAS in the subject well to mitigate the sand problem and minimize cost due to NPT (Non-Productive Time) of the rig. SAS was installed and the potential zone in UN-X could be tested successfully with tubing PCP. No sand problem was observed during testing and after testing while clean out operation there was no sand.

Results, Observations, Conclusions
Well test showed an average liquid rate of 124 BFPD with 37% WC (predominantly completion brine). The well was put on production on November 2016 and producing till date without any sand problem.

Novel/Additive Information
This paper will include discussion on the approach used to select a sand control method for cold and heavy oil production. The results of sieve analysis was in the middle between sand screen and gravel pack but based on the team experience in sand control and the nature of heavy oil and its relatively low oil production rate, the decision was made to install SAS and that was proved to be prudent decision.
Improving the Decision Making for Heavy Oil Field Development Projects Using the Fuzzy Analytical Hierarchy Process FAHP
Authors: Passalacqua Herminio , Qubian Ali 
Published: December 2018

Abstract
The selection of the best EOR option for optimizing the recovery in a field development plan is probably one of the most difficult decisions, as many parameters and options, as well as uncertainties play a role difficult to rank and characterize. This work presents the application of a new methodology, Fuzzy Analytical Hierarchy Process (FAHP), aimed to select the best EOR option, illustrating its practical application to a heavy oil field development case.
In order to rank efficiently prospects opportunities and exploitation scenarios the most common approach is the evaluation based on economical parameters. However, technical parameters like well-types options, facilities configurations, transport options, operability, and reliability, are not strictly, nor solely economical parameters, hence, not easily considered during the screening and selection phases of the FEL (Front-End-Loading) process. When the number of options and parameters becomes very large, the human judgement must be supported by some kind of logical methodology or Multiple Attribute Decision Making (MADM) methodology.
One of these methodologies is the FAHP (Fuzzy Analytical Hierarchy Process) which is a modification of the Analytical Hierarchy Process (AHP) tested previously for the development of a heavy oil field in the pre-FEL stage aiming to improve the decision-making process, including technical elements in addition to the conventional economic parameters.
The application of the FAHP technique is analyzed in this work, deriving conclusions of interest when dealing in field development decisions that require decisions from a group of experts.
Application of Supercritical Water Coupled with Toe-Point Injection Technique for Heavy Oil EOR: A Case Study
Authors: Qu Shiyuan , Jiang Hanqiao , Li Junjian , Hu Jinchuan , Sun Fengrui , Qiao Yan , Dong Mingda , Chen Wenbin , Zhou Yu 
Published: December 2018

Abstract
Heavy oil is an important part of unconventional resources. Many great breakthroughs have been made in heavy oil EOR mechanism of thermal methods. With the unprecedented development of technology, Super-critical Water Coupled with Toe-point Injection Technique is entering people’s view.
Compared with previous thermal methods, the reservoir can be heated to a higher temperature by injecting supercritical water, obtaining a larger heated radius. Meanwhile, toe-point injection could abate the problem of early channeling and unequal steam absorption caused by heel injection in extremely long horizontal wellbore or reservoir of serious heterogeneity, which results in a higher recovery rate.
In this paper, a novel topic is discussed on the effect of different parameters on oil productivity during the single horizontal well production process, using discrete horizontal well model. The recovery process is completed through a single horizontal well--the supercritical water is injected into the reservoir through the tubing, while oil is produced to the surface through the annulus. Some meaningful conclusions are listed below.
(a) Under the same production policy, the recovery ratios of supercritical water are generally higher than those of steam, indicating that, besides its chemical reactions with heavy oil and rock minerals and fracture initiation ability, the effect of physical properties (high pressure and high temperature) on oil recovery efficiency also play an important role in the usefulness of supercritical steam in heavy oil recovery. (b) The relative well height in the reservoir has significant influence on the production performance, whose impact varies as the production methods change. Consequently, the optimum well position ns under diverse production methods are different. (c) The direction of oil recovery is from toe point to the heel point. The matching between well height and the growth of steam chamber and water puddle decides the production performance.
Effective Matrix Acidizing Based in Chelating Agents: A Case Study in Romanian Heavy Oil Reservoirs
Authors: Panait Emil , Isac Constantin , Marton Csaba , Dos Santos Arlinda , Girardi Stefano 
Published: December 2018

Abstract
Heavy and extra-heavy crude oil reservoirs hold physicochemical characteristics that can frequently turn their operation into a technical and economic challenge. Typically, heating techniques are used to decrease oil viscosity. Areas with steam injection are susceptible to developing formation damage mechanisms such as scale precipitation that gradually restricts the flow of fluid towards the wellbore and ultimately decreases overall well productivity and/or injectivity. Acidizing treatments to either remove obstructing scale or to further increase near wellbore permeability are handled with caution: heavy oil is very sensitive and interaction with such conventional acids include asphaltene precipitation, sludge and emulsions.
Suplacu de Barcau is a shallow, heavy oil reservoir (16°API average) located in the northwestern part of Romania. It has been successfully operated with aid of both in-situ combustion and steam injection since 1960. Scaling tendency of condensed water from steam and its incompatibility when mixed with formation water frequently ends in scale build-up in injector and producer wells respectively. Identifying a fluid able to clean-out the scale deposits while being fully compatible with sensitive heavy oil, involved extensive screening a compatibility testing protocols. A formulation based on the chelating agents N,N, Glutamic Acid Diacetic Acid (GLDA) and Diethylene Triamine Pentaacetic Acid (DTPA) were found not only to effectively dissolve the plugging materials, but remarkably it was also noticed that it reduced significantly the oil viscosity, which made this formulation the most appropriate treatment for field application.
A number of 10 producer wells treated with the GLDA and DTPA based fluids delivered promising results by increasing oil rates by 3- 6 times of increase, significant improving steam coverage and penetration, decreasing drawdown and skin and ultimately enhancing the mobility of asphaltic oil. This paper describes the stimulation approach followed from diagnosis, fluid screening and selection, treatment design, job execution and results. Furthermore, the outcome of this stimulation campaign has shattered the myth that this type of stimulation does not work in hard oil.