bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Applications of Laser Technology in Downhole Operations - A Review
Authors: Adeniji Adewale Wasiu 
Published: May 2016

Abstract
Downhole operations in the petroleum industry include drilling and completing the well for production. Experiments conducted on different types of lasers have shown the potential of the cutting - edge technology being applied in downhole operations. One of the tests was conducted on MIRACL (Mid Infrared Advanced Chemical Laser) to determine its feasibility for drilling and perforating petroleum wells and another was on COIL (Chemical Oxygen-Iodine Laser) to determine the least specific energy (SE) needed to destroy varying rock types. This paper presents the applications of laser technology in downhole operations such as drilling, perforation, stimulation, vaporizing stuck pipes, tracer detection, treatment of asphaltene deposition and cutting of subsurface equipment such as casings, tubing strings etc. Its benefits are presented in terms of effects on Rate of Penetration (ROP), operational downtime, formation damage, clay treatments, flow enhancement and overall well deliverability. Laser technology has been utilized successfully in the medical industry, manufacturing industry, nuclear industry etc. Therefore, its applications in downhole operations are major strides in the petroleum industry and a means of optimizing downhole operational practices. It has been reported that integrating laser technology with conventional drilling technology will immensely improve drilling efficiency but this has not been so far applied in the field. Conclusions derived from a two year project funded by The Gas Research Institute (now Gas Technology Institute) in 1997 on "Adapting Star Wars High-Powered Lasers to Drilling Natural Gas Wells," are that lasers can cut rock of all lithologies; shear power shares importance in cutting rock with such parameters as wavelength, purge gas pressure and hole size; and historical and widely accepted theoretical calculations of the laser power needed to spall (break), melt and vaporize rock are significantly higher than experimental values. Just like any new technology, laser technology has its challenges and they are highlighted accordingly.

Introduction
The most reliable way to detect oil and gas is by drilling an oil well. From the onset, oil wells have been drilled using cable tool (percussive) drilling method. This method of drilling was gradually replaced by rotary drilling in the twentieth century. As Research and Development progresses, laser drilling was developed in the 90&apos;s. An oil well needs to be completed to flow the well. Well completion includes casing, cementing, perforation, stimulation etc. Various studies have been conducted to evaluate the suitability of this breakthrough technology in downhole operations and they have all yielded positive results.
Gtl Efficiency
Authors: Al-Tamimi Abdulaziz 
Published: May 2016

Abstract
A number of key parameters have been used for defining the efficiency of GTL (Gas-to-Liquids) process. The most commonly used bases are Carbon Efficiency (CE) and Thermal Efficiency (TE). This paper discusses the definition of each of them and the significant developments that have occurred and have been expected on the key focus areas of GTL efficiency improvement.
Both CE and TE should be maximized to the extent of technically feasibility and economical justification to ensure responsible and sustainable utilization of natural resources. Nowadays, the GTL technology CE and TE are considered drawbacks of the GTL technology and as a consequence considerable efforts are being made by technology developers to reduce the inefficiencies.
The current generation of the GTL technology has a typical plant wide CE of 70–75 % and a typical plant wide TE of 57–61%. Although GTL efficiency is still low compared to conventional refineries and LNG plants, it has been improved significantly over the last two decades.
Further improvement can be expected over time as the GTL technology has not gone through the same degree of technological improvement as the conventional system. Advances in GTL technology are projected to increase the efficiency within the next decade as such it would be comparable to conventional refineries and LNG plants that have CE and TE of around 90% and 73% respectively.
Multiphase Flow Meters Trial Testing in High GOR/GVF Environment
Authors: Nasri Ahcene , Al-Anizi Abdulaziz , Al-Amri Meshal A. , Al-Khelaiwi Faisal T. , Al-Anazi Ammal 
Published: May 2016

Abstract
Multiphase flow metering (MPFM) technology is gaining popularity and becoming the main well rate testing mechanism in some regions of the world. Yet, their application in measuring the flow rates of high gas-oil-ratio (GOR) and/or high gas volume fraction (GVF) wells has always been a challenge. A remote field located in the Southeastern part of Saudi Arabia commenced its production in the late 90's from a thin oil column lying between a large gas-cap and a water aquifer. Although, 84% of the thin-oil-column producing wells are horizontal and multilateral wells with extended reservoir contact, the gas-cap gas breakthrough and production from these wells have increased gradually; resulting in an increase in the wells GOR. Currently, 35% of the wells are producing at high GOR ranging between 2,000 and 6,000 SCF/STB with a GVF reaching as high as 98%.
The fluid flow rate tests of these wells are conducted through a test separator designed to handle a GOR of 2,500 SCF/STB; well below the current GOR of these wells. Such plans require identification of the most appropriate MPFMs that can operate successfully in such high GOR/GVF conditions.
This paper describes the field trial test of three MPFMs under high GOR/GVF conditions of dry and wet production. The meters' performance is compared to a portable test separator properly sized to accommodate the high gas and liquid flow rates of the producers of this field. The paper summarizes the results of this test and justifies the measurement errors in light of the operating principle of each meter. The paper also provides valuable guidelines for conducting such testing operations by building on the lessons learned from this trial test.
Ultrafast Determination of Archie and Indonesia m&n Exponents for Electric Log Interpretation: a Tight Gas Example
Authors: Bona N. , Rossi E. , Bam B. 
Published: May 2016

Abstract
It may take several months to measure the Archie or Indonesia parameters of a tight rock. As a result, a long time elapses between the acquisition of electric logs and their final interpretation. We describe a method that provides reliable measurements of these parameters in one day. The method combines NMR and electrical determinations. The latter are performed using a patented 4-contact cell. A description of method is given and a tight sand case study discussed.

Introduction
Resistivity Index (RI) is defined as the ratio of rock resistivity at any given water saturation (Sw) level to its resistivity when completely saturated with water. All labs measure RI at a number of different average saturations. The greatest source of error in these measurements is the heterogeneity of Sw. Even a small Sw heterogeneity may have a strong effect on RI test results and can translate into significant errors in the log-derived saturations.
Consider, for instance, the rock sample sketched in Fig.1. The sample is comprised of two regions having different saturations. Let Sw1 be the saturation of the higher Sw region and a·Sw1 the saturation of the lower Sw region (0&lt;a &lt; 1).
Dukhan Field CO2 Injection EOR Pilot: Reservoir Modeling & Planning
Authors: Ozen Ozgur , Wahlheim Thomas A. , Attia Tarak , Barrios Levin , Bin Ab Majid Mohamed Naguib , Wilkinson John 
Published: May 2016

Abstract
A reservoir study was conducted to plan a near-miscible CO2 gas injection pilot in the Dukhan Field with the following study guidelines:Determine overall objectives and timeframe for the pilotDesign the pilot to meet the objectives and timeframePlan the pilot in a portion of the field with representative reservoir descriptionPropose a surveillance and monitoring plan to ensure high quality information is obtained for interpreting the pilot performanceDesign the pilot so the recovery processes are scalable to larger well spacing for reservoir-wide application
Using these guidelines, the following pilot objectives were developed:Provide data on well injectivity and productivityReduce uncertainty in the estimation of incremental oil recovery from CO2 gas injection relative to waterfloodProvide data to allow commercial scale well and facility CO2 gas injection designMinimize the impact on current operations outside the pilot area
The results of the reservoir modeling study provided the detail for well orientation and placement to satisfy the pilot objectives at a reasonable cost and within appropriate timeframe for information gathering, analysis, and commercialization decisions. The reservoir model pilot area selected is one kilometer square segment in a crestal structural location that does not contain active wells and is near existing surface facilities. The reservoir description data used for the segment models were extracted from history matched full-field reservoir models. The proposed pilot wells are located within close proximity of each other to achieve gas breakthrough and oil bank arrival within the proposed pilot evaluation period of two years. The pilot design ensures that the pilot would allow for data gathering of key project design information; such as injectivity, gas breakthrough timing, oil displacement, and reservoir sweep.

Introduction
The large, mature Dukhan Field is located onshore Qatar, approximately 80km west of Doha. It is a north-south plunging anticline approximately 70km long by 8km wide. The field was discovered in 1939 and first production occurred in 1949. The field has more than 750 well penetrations. The major oil reservoirs are the Upper Jurassic Arab C and Arab D. There are lesser amounts of oil and gas in the Middle Jurassic and non-associated gas in the Permo-Triassic Khuff formation. The Arab C reservoir was initially filled with over 1400ft of oil between the structural crest and the oil-water contact. The Arab D reservoir was initially filled with over 700ft of oil rim in equilibrium with 700ft of gas-cap.
Fibre Optic Sensing For Improved Wellbore Production Surveillance
Authors: van der Horst Juun , Den Boer Hans , In 't Panhuis Peter , Wyker Brendan , Kusters Roel , Mustafina Daria , Groen Lex , Bulushi Nabil , Mjeni Rifaat , Awan Kamran Fahmeed , Rajhi Salma Mohammed , Molenaar Mathieu M , Reynolds Alan , Paleja Rakesh , Randell David , Bartlett Richard , Green Kevyn 
Published: May 2016

Abstract
Since our previous publication1 significant progress has been made to further mature the application of Fiber-Optic (FO) based Distributed Acoustic Sensing (DAS) for production and injection profiling. A considerable number of new field surveys were conducted to further improve the evaluation algorithms or workflows which convert the DAS noise recordings into flowrates from individual zones. For gas producing wells, a new graphical user-interface has been developed that allows the user to visualize and QC the data in real time. Additional flow and visualization software have been developed for single phase gas producers to enable the user to select and evaluate the data in a user-friendly manner using the most up-to-date evaluation algorithms.
There are still improvements to be made in enabling Distributed Sensing infrastructure, such as handling and evaluation of very large data volumes, seamless FO data transfer, the robustness & cost of the FO system installation, and the overall integration of FO surveillance into traditional workflows. It will take some time before all these issues are addressed but we believe that FO based applications will play a key role in future well and reservoir surveillance.
In this paper we present two recent examples of single-phase flow profiling using DAS. The first example is from a single-phase gas producer in one of the Unconventional plays in North America and the second example is from a long horizontal, smart polymer injector operated by Petroleum Development Oman (PDO).

Introduction
In oil and gas field development there is often a lack of high quality Well and Reservoir Surveillance (WRS) data for quality decision making; leaving significant reservoir or well performance uncertainties potentially leading to suboptimal reservoir development. The need for frequent and good quality surveillance data is highest in complex reservoir developments such as Unconventional plays, waterflooded reservoirs, Thermal and Chemical Enhanced Oil Recovery (EOR) projects. One of the reasons that well surveillance data is not acquired in practice is that it often causes significant production deferment. Another reason is that often the data gathering surveys are expensive or create large operational risks associated when using conventional logging methods, particularly in high rate, highly deviated or long horizontal producer wells. In some cases, the small diameter production tubing limits access to the well with conventional logging tools.
Processing and Preliminary Interpretation of the Ultra High-Density Full-Azimuth 3D Seismic Survey, Dukhan Field, Qatar
Authors: Seeni Salvarajeh , Setiyono Kriyanti , Zaky Hala , Snow John , Weber L. James 
Published: May 2016

Abstract
The Dukhan Field 3D seismic survey is an ultra high-density wide azimuth survey (i.e., point source and receiver, short source and receiver line interval, and full azimuth recording) intended to provide a significant uplift in quality and resolution to enable the imaging of reservoir sub-layers and fine-scale structural features.
This paper presents the challenges and lessons learned from full-field processing and inversion. Seismic interpretation demonstrates added value to the field, which leads to improved reservoir models and support to well operations through improved well placement. Subtle structural, stratigraphic, and diagenetic features are now imaged.
Knowledge gained from processing this survey includes:cost, time, and effort invested on the Dukhan 3D survey is worthwhile as high quality results are obtained at 15m bin processing;3.75m bin processing is now possible, and could be performed to improve image quality over the full seismic bandwidth for all reservoir intervals;Pre-Stack Depth Migration (PSDM) workflow is recommended for optimal offset and azimuth reconciliation and noise attenuation;the adverse effect of near-surface geologic variability on seismic data quality can be improved by utilizing microgravity and resistivity (Vertical Electrical Sounding) techniques; andproper preconditioning of the input data is critical for reliable prediction of reservoir properties away from well control.
While industry's knowledge and experience in acquisition and field operation of ultra high-density full-azimuth seismic has increased over the last 3 years, processing of such data to ensure optimal imaging and reliable reservoir property predictions (e.g., porosity) has lagged. QP believes that lessons learned through this round of processing can provide insight for prediction of rock properties in the major Dukhan reservoirs.

Introduction
The Dukhan field is located along the south west coast of Qatar, extending 70 kilometers north-south (Figure 1) and is one of three giant oil and gas fields in which Qatar Petroleum (QP) retains 100% interest. It was discovered in 1939 and has produced from three oil reservoirs (Arab-C, Arab-D, Uwainat) and one gas reservoir (Khuff). It is the only onshore field in Qatar and more than 750 wells have been drilled to date. Over the past 70 years, the hydrocarbon development and production history at Dukhan has undergone several phases. Initially, the oil and gas reservoirs were produced using natural pressure depletion. Water injection was started in the mid to late 1960's as pressures begin to fall. A more efficient power water injection system and horizontal well technology were introduced in the late 80's.
Modeling Tectonic Heat Flow and Source Rock Maturity in the Rub
Authors: Abdul Fattah R. , Meekes S. , Bouman J. , Ebbing J. , Haagmans R. 
Published: May 2016

Abstract
A 3D basin modeling study was carried out to reconstruct the regional heat flow and source rock maturity in the Rub'al-Khali basin. Gravity gradient data from the GOCE satellite were used to model deep structures, such as the Moho interface. Tectonic heat flow was modeled using the GOCE-based Moho interface to reflect heat flow variations in the basin though time and space. The thermal maturity of Silurian and Jurassic source rocks in the Rub'al-Khali was calculated using the GOCE-constrained basal heat flow model. GOCE-based Moho depth map was calibrated to data from known seismic stations in the region. This map provided input to constrain the heat flow in eth basin. Modeled heat flow values are consistent with known values of heat flow in the region. The model indicates that the Silurian and Jurassic source rocks are generally in the hydrocarbon generation window and the modeled maturity trends are in agreement with the observations in the area.
Developing disruptive and revolutionary new generation seismic technologies for the Middle East
Authors: Hwang Jay , Baeten Guido , Walk Wim 
Published: May 2016

Extended Abstract

Summary
We present the business and technical underpinning for developing revolutionary onshore and offshore seismic acquisition technologies in order to meet the challenges of the new E&P business portfolio. In this paper we will also describe new seismic acquisition systems developed with external technology partners and report their progress. These new systems aim at disrupting both the onshore and offshore seismic industry by delivering accurate and high quality seismic data with significant cost improvement. For land Shell is pushing toward a million channel system development in order to drastically drive the cost down with high receiver and source efficiency, and strongly improve the seismic quality with WAZ, long offsets, and broad bandwidth for surface seismic. This system also targets permanent reservoir monitoring. For offshore applications, a multi-source fast deployed ocean bottom node (OBN) system is being developed to drastically reduce the survey cost such that it can be cost effectively applied to large exploration surveys as well as higher resolution surveys for 4D. Shell expects to commercialize these new technologies with partners in order to deploy them to Shell assets in the nearer term and to the industry in the longer term.

Introduction
Remaining onshore conventional exploration targets tend to distribute in areas where reservoirs are associated with structurally complex geology or lie beneath highly variable near surface or structurally complex overburden. With unconventional hydrocarbon opportunities, delineating sweet spots presents even more challenges. Current seismic acquisition and processing techniques are insufficient to characterize these difficult reservoirs. Seismic images with a quality similar to those emerging from offshore environments are necessary for better exploration and production decisions in these challenging onshore areas.
E-Technology: A Key for Excellence in Training Geosciences
Authors: Dekeyser Dominique , Machhour Louai , Vedrenne Valerie 
Published: May 2016

Abstract
Training is a major challenge in oil &gas companies because of the rich diversity of cultures and generations. Since our aim is to provide the same skill development opportunities to every Total employee, we need to develop a worldwide access to quality training that is up to our standards. The expected high rate of seniors' retirement imposes the need to find ways of preserving departing experience. Our technical studies are complex and use concepts and tools that rapidly develop with time. Training must address these issues, and be provided faster and at lower cost.
Traditional classroom courses need to be reconsidered in the light of these requirements and of the development of new technologies, as far as computing and pedagogical aspects are concerned. Furthermore, Total has developed a personalized internal apprenticeship and a training path, supported all along the career, which combines technical and personal development.
The search for fit-for-purpose new ways of training leads us to promote: – Distance learning studios to share specialists' know-how (e.g. distant coaching from our Headquarters Training rooms), – Course capturing and broadcasting to build on experts' experience (e.g. preserving the knowledge of departing seniors), – New in-the-field geosciences pedagogy with interactive tools (e.g. richmedia resources to enrich courses on the field), – Immersive training techniques to become operational more quickly (e.g. interactive drilling rig) – Fast learning modules (e.g. e-learning) monitored on in-house training platform.
In other words we are experiencing a revolution in training content and training media. The learning process is based more and more on "real life" situations and modular courses to gain in flexibility. The presentation gives detailed and practical examples of these new tools that are targeted towards our geosciences technical staff worldwide.
Innovative Well Intervention Techniques to Sustain Production in Mature Offshore Fields
Authors: Koshy Noble Sam , Anand Saurabh , Vadapally Sai Rakesh Varma 
Published: May 2016

Abstract
Cairn India is an operator for two mature offshore fields in India – Ravva and CB/OS-2. Due to high offshore rig cost combined with cost recovery risks, innovative well intervention techniques are implemented in both the fields to sustain production & enhance injection. This paper summarizes some of the successful well intervention cases over the past few years and how it changed the approach towards meeting production targets.
Case 1: Slickline conveyed straddle gas lift technique to activate and produce from a previously shut-in well.
Case 2: Wireline conveyed robotic tools to retrieve downhole screen and restore well injection.
Case 3: Modular CT units and advanced downhole tools for well stimulation improving production by multiple folds.
Case 4: Specific chemical system to successfully complete a vessel based stimulation campaign in water injectors; this led to an overall two-fold increase in the field injection rates.
Case 5: Advanced downhole camera to identify wellbore held-up reasons during regular interventions and how it has led to several important decisions saving time and cost.
The operator always looked at challenging problems as opportunities for innovative solutions. The above interventions were focused on well revival using cost effective and innovative well intervention techniques avoiding rig based workover and achieving the objective in all the above cases. A synopsis on the recently completed cases and future inventive solutions is covered in last section of the paper.

Field Introduction
Ravva is located 10 kms off the shore of Godavari Delta on the east coast of India. The anticline structural reservoirs are multi-Darcy sands of Middle Miocene age. The field oil is light with an API gravity of 35o and GOR of the range 470 – 520 scf/bbl. The field was developed through 8 unmanned platforms with production commencing in 1993. Water injection was introduced in 1997 for reservoir pressure management and is the supporting drive mechanism. Water-oil displacement characteristics are excellent due low oil viscosity, high permeability, low residual oil saturation and good areal pressure communication. Almost all wells are producing with Gas injection for artificial lift. After a sustained plateau production period of 50,000 bopd, the field currently is on decline with increasing water cut (average water-cut ranging from 60% - 90%).