bluuebunny/crossref_metadata_2025_split huggingface dataset:
Engineering Standard Project Packages
Authors: AL Katheeri Salem Omar , Samad Khalid Abdul 
Published: November 2016

Abstract
Objective:
Development of engineering standard project packages has major benefits in establishing a design baseline project model across assets engineering. This enable bench marking for continuous product improvement process.
This resulted in optimizing resources, achieving sustainable production rate and Key performance indicator due to minimize project life cycle.
Methods, Procedures, Process
The methodology is an engineering approach that creates product baseline for continuous engineering challenges to drive optimum engineering standard project packages.
Result and conclusions
The final conceived product is now currently utilized by all engineering asset. The most significant benefits gained and realized are as follows: Shorten project life cycle. Reduction of 10 - 12 months of tendering and award for Front End Engineering Design execution.Minimize design variances across Assets resulting in optimized design.Support higher management initiative Long term strategy project - Capital Efficiency.Ensure common best practices & engineering procedures are adhered to.Meet production injection targets (for delivering water injection and artificial lift technical packages) prior the declining of wells.
The final conceived product is engineering standard project packages that we have benchmarked with similar oilfield companies. As a result we have yielded skid mounted modular unit that have vast greater advantages than current design. We have achieve 30% reduction in final cost of product from standardizing engineering project packages
Novel
The novelty of the new standard engineering packages project is creating project baseline for future continuous improvement process cycle to achieve optimum comprehensive design.
Hence enhancing project design wll drive better product life cycle cost and ensures inherited values are continuously integrated and inbuilt in final product.
Detection of Failures and Interpretation of Causes During Drilling Operations
Authors: Skalle Pål , Aamodt Agnar , Swahn Isak 
Published: November 2016

Abstract
A majority of the remaining oil and gas reserves are located on continental shelves. Offshore drilling operations are expensive, and the numbers of wells are therefrore held low, and they tend to be long and complex. The number of process failures seen in recent years does not exhibit the intended declining tendency. A failure during drilling operations is defined as the state when non-productive time is occurring.
The motivation behind the work presented here is to advance a specific computerized method for helping the petroleum industry in reducing unwanted downtime. More up-time is needed. The ultimate goal of our research is to improve the drilling process quality and efficiency. This is achieved by first detecting process deviations (symptoms) during the drilling process, and produce explanations generated by a general knowledge model (ontology). The symptoms have been translated into formal concepts and related into cause-effect relationships with errors and failures.
Our experimental system is able to read data from a drilling process and apply the on-line detected and predefined static symptoms to capture a probalistic understanding of the downhole process. We will demonstrate the tool's ability during selected drilling processes to determine which failure type is the most threatening during problem situations and which errors are causing the failure. The failures revealed by the tool on basis of detected symptoms are compared with the reported failure in the field.
Mega-Extended-Reach Drilling to Deepwater Target: What is the Well's Maximum Allowable Measured Depth While Drilling?
Authors: Chen Xuyue , Gao Deli 
Published: November 2016

Abstract
Mega-extended-reach wells (MERWs) can be drilled from one platform to develop the remote surrounding satellite oil & gas reservoirs in deepwater. Though the platform is located in shallow water, some MERWs can be targeted the reservoirs in deepwater. In mega-extended-reach drilling (MERD) to deepwater target, some challenges that may be faced are the presence of low temperature, typically weak overburden sediments, unconsolidated formations and a small sedimentary coverage above the reservoir. This results in a narrow safe mud weight window (SMWW) and a limited well depth for MERD operation. In this work, considering the pressure balance of bottom hole including the thermal and seepage effects, a method for predicting the maximum allowable well depth (MAMD) of MERD to deepwater target is presented. Meanwhile the factors affecting the MAMD of MERD to deepwater target are also investigated. The study shows that seepage significantly affects the MAMD of MERD to deepwater target while the thermal's effect is not very obvious, seepage turns out to significantly decrease the MAMD whereas heating the formation is found to be helpful in extending the MAMD. It also shows that the predicted MAMD of MERD turns out to be obvious anisotropy, drilling in the direction of minimum horizontal in-situ stress in the formation is prone to attain a wider SMWW and a longer MAMD than other directions. Moreover, for a given target zone, the MERD with a horizontal bottom hole has a much longer MAMD than that of MERD with an inclined bottom hole, and the MAMD can also be effectively increased by reducing the annular pressure loss. This work provides a practical tool for enhancing the design of MERWs to develop the remote satellite oil & gas reservoirs in deepwater.
Coiled Tubing Telemetry System Improvements with Real-Time Tension, Compression, and Torque Data Monitoring
Authors: Blanco Diego , Rahimov Khalid , Livescu Silviu , Garner Louis , Vacik Lubos 
Published: November 2016

Abstract
Real-time depth, pressure, and temperature data monitoring is currently available for well interventions with coiled tubing (CT). A recently-developed extension for real-time forces (i.e., tension and compression) and torque data monitoring has been added to a robust CT telemetry (CTT) system, allowing further optimizations in operations such as milling, cleanouts, fishing, and extended-reach applications.
The real-time CTT system consists of a non-intrusive electrical conductor wire inside the carrying CT, surface hardware and software, and three versions of bottom hole assemblies (BHAs) in different sizes: 2 ⅛-, 2 ⅞-, and 3 ½-in. Each BHA incorporates a conductor release assembly, a casing collar locator (CCL), pressure, and temperature sensors, and a BHA release function. In addition, the tension, compression and torque (TCT) assembly has been developed for the 2 ⅞-in. BHA. Switching between applications is as simple as changing out the BHA, which reduces the need to rig-up and rig-down and leads to operational time and cost savings. The main advantage of this system is that it eliminates the downhole uncertainties such that the CT field crew can react to changing conditions, making decisions based on dynamic downhole events and eliminating missed or wasted runs.
Several CTT case studies have been recently presented (SPE-174850-MS and IPTC-18294-MS). The recently developed TCT assembly development and initial laboratory testing results have been also presented (SPE-179101-MS). In this paper the TCT assembly temperature calibration results and field testing are presented showing that combining the TCT data with depth, pressure, and temperature data in real-time increases the job efficiency and control.
The paper describes the TCT assembly and its temperature calibration and discusses the TCT data acquired during the first field trial. The CTT system performance and benefits confirmed during the field trial are presented. These findings outline the predictability of successful operations resulting from using the CTT system and the cost and time savings for operators.
High-Temperature Acidizing: Advantages of Inhibitor-Intensifier Synergy
Authors: Syafii Irfan , Pandya Nisha , Sabhapondit Anupom , Hajj Hicham El 
Published: November 2016

Abstract
High-temperature acidizing operations are challenging because of the highly corrosive nature of acids. Hydrochloric (HCl) acid has an especially high reaction rate, which increases the rate of tubular corrosion. In addition to the type and concentration of acids, factors such as temperature and metallurgy influence the rate of corrosion.
To meet increasing demand for deeper stimulation at high temperatures, emulsified acid is predominately used. It contains acid in the internal phase and oil in the external phase, forming an invert emulsion. The outer oil phase creates a barrier for acid, allowing its slow release for reaction with reservoir rock. Emulsified acid systems provide several advantages compared to plain acid. The oil barrier especially helps with preventing corrosion by significantly reducing the contact of acid with the metal tubular. High fluid viscosity helps reduce fluid loss, distributes the acid more uniformly in the formation, and reduces the rate of corrosion.
Selection of the proper corrosion inhibitor(s) is one of the most important criteria for high-temperature acidizing. The use of intensifier(s) with the inhibitor enhances the corrosion inhibition significantly. This makes it possible to use a higher concentration of HCl acid at temperatures as high as 350°F, thus enhancing the fluid efficiency. In this work, several corrosion inhibitors and intensifiers are studied at varied acid strengths and temperature conditions. To achieve good corrosion control, a synergy is required between corrosion inhibitors and corrosion inhibitor intensifiers. At the same time, they should not negatively impact the emulsion stability. A new emulsified acid system was developed using HCl acid strength up to 28%. High corrosion control imparted by inhibitor-intensifier synergy coupled with the slow reaction rate of emulsified acid makes this blend unsurpassed for use in extreme high-temperature conditions up to 350°F.
This emulsified acid system has the potential for use in the Khuff formation of Saudi Arabia with the addition of a H2S scavenger. Testing with a commercially available scavenger exhibited good compatibility with the blend.
Testing and Characterization of Shock and Vibration Loads to Enhance Drilling Tool Reliability and Efficiency
Authors: Heinisch Dennis , Oueslati Hatem , Popp Timothy M. , Meyer-Heye Bernhard , Schepelmann Cord , Reckmann Hanno 
Published: November 2016

Abstract
This paper presents an investigation of true downhole dynamic conditions through improved testing methods and a new measurement-while-drilling (MWD) tool. Shock loads may cause severe damage to bottomhole assembly (BHA) components. Consequently, characterizing the shock loads and analyzing their distribution within drilling tools produces information for the design process that can improve tool reliability and efficiency.
The difference between shock loads and traditional dynamics is rarely discussed within the drilling industry, so this paper first introduces a mathematical description of shocks. Experimental shock and vibration tests are used to investigate the shock and vibration loads experienced by full-scale downhole drilling tools. The test rigs for this effort enable testing of full-scale drilling tools as long as 10 m and a maximum weight of 2 tons. Testing of entire drilling tools, and the emulation of downhole conditions, enables realistic dynamic loading and an analysis of the interaction of tool internal components. These results are not possible when testing single components on a vibration table. During the tests, acceleration sensors positioned at several locations on the outside of the tool body measure the shock amplitude. Simulation models enable analysis of the load distribution within the tested tool. Depending on the simulation results, the reliability of all internal components can be ensured. If necessary, further design improvements are initiated.
The simulation models are validated and improved with data from experimental modal analyses of the test rigs and the tested tools. Identifying uncertain parameters for complex dynamics simulation models is a particularly challenging task. Results from the shock tests are compared to the simulation results for additional validation because shock loads, in contrast to typical vibrational loads, are transient. Shock and vibration tests also serve to evaluate the capabilities and limits of current MWD tools in terms of sampling rate and sensor range. A newly developed MWD tool for dynamics measurement was tested, evaluated, and optimized using this testing process.
The tests and simulations enable optimization of drilling tools for shock and vibration loads. In contrast with the limitations of historical measurements, enhanced dynamics-measurement capabilities with higher sampling rates and extended sensor ranges provide increased data quality and better characterization of downhole shock and vibration loads. This improved understanding of drilling dynamics loads leads to reliability enhancement and cost optimization by reducing shock and vibration-related tool failures.
Harmless Treatment Technology of Oily Cuttings
Authors: Li Guanghuan , Ma Hong , Long Tao , Huang Daquan , Tian Zengyan , Zhang Aishun , Wang Weizhong , Hou Shili , Gong Chunwu 
Published: November 2016

Abstract
Oily cuttings are hazardous wastes containing oil, hydrocarbons and heavy metals, which generate a significant risk to human and enviroment without appropriate treatment. The common treatment, including heating, burning, microbiological degradation and so on, are not fast and effective enough to solve the pollution problem caused by oily cuttings. This article provides a method with higher efficiency and lower cost. An intelligent cleaning agent, synthesized for cleaning oily cuttings, is easy to dissolve in water and makes oil and water easily emulsify during cleaning process, so as to achieve the purpose of removing oil. By adjusting the pH, the emulsion will be automatically demulsified after statis, and then the oil and water are separated from each other, which simplify the progress of treatment. Ultrasonic technology is assisted to clean the oily cuttings, which effectively reduces the amount of cleaning agent and increases the treating efficiency of the cleaning agent. In this paper, the effects of the cleaning agent dosage, heating temperature and ultrasonic time on the deoiling ratio are analyzed. The oil recovery rate is above 90% with the dosage of 7.5g/L oil cleaning agent under the 55 °C and 10 minutes. The recovered oil has good quality and meets the demand for preparation of oil-based drilling fluid. The residual wastewater, including the cleaning agent, can be reused as cleaning liquid by adjusting the pH to neutral and adding fresh cleaning agent. This technique improves the treating efficiency of oily cutting and greatly lower the cost, which would have a high value to popularize.
New Ideas and Approach to Engineering in Brown Fields- A Case Study on Instrumentation in Offshore Projects
Authors: Vasudevan M. , Shabaka Ashraf , El-Sawah Mohamed , Moro Sudhakar A. , AL-Obeidli Ibrahim 
Published: November 2016

Abstract
A trend already emerging is that companies are putting greater emphasis on ‘doing the right project' which means more focus on quality decision making, feasibility studies and pre-FEED activities. In the current challenging economic environment, Maximizing production from existing assets is becoming the utmost priority and hence brownfield modification projects are being vigorously being pursued worldwide. Remote locations and/or challenging environmental conditions mean that any modification to an existing facility requires meticulous investigation and planning. There is no substitute for early and focussed engineering work to drive towards an optimal cost and schedule.
This paper provides insight into the how ADMA's planning in Automation in Brownfield projects has ensured productivity and cost effectiveness in recent project delivery.
Brownfield production expansion projects differ greatly from Greenfield work. Greenfield topsides facilities can be engineered to be discrete, self-contained modules, capable of being lifted in place onshore and transported as part of an integral floating structure or floated offshore to be lifted into their final position.
Interpreting Total Organic Carbon TOC in Source Rock Oil Plays
Authors: Steiner Stefan , Ahsan Syed Asif , Raina Ishan , Dasgupta Suvodip , Lis Grzegorz P. 
Published: November 2016

Abstract
Total Organic Carbon (TOC) is a critical parameter to determine reservoir quality of any source rock play. Carbon is present in all organic components of a rock, namely, kerogen, bitumen and hydrocarbons. However, properties like maturation of the organic matter and hydrocarbon type influence TOC measured on both core or determined from logs. TOC in a gas-bearing source rock play mostly denotes carbon associated with kerogen as carbon density of gas is generally too low to be detectable. In an oil bearing source rock play, TOC is a mix of kerogen, bitumen and liquid hydrocarbon.
In this paper, we investigate TOC as a combination of 1) Kerogen Hosted Carbon, and 2) Extractable Organic Matter (EOM). The value of using individual organic matter components in petrophysical modeling and its impact on results is presented using examples from an oil window source rock play in the Middle East. A critical examination is carried out of the different log-based TOC methods and their sensitivities to different organic carbon constituents. With a focus on oil window plays, recommendations are provided on core-log calibration.
Simple qualitative methods utilizing rock pyrolysis results and log-based TOC estimation methods to evaluate reservoir quality are presented. Such an analysis is particularly useful to source rock plays in the oil window.
Rock-Eval pyrolysis is commonly used to estimate maturity in unconventional plays. However, for plays in the oil window, maturity estimation can be hampered due to Tmax suppression in the presence of bitumen (e.g., Snowdon 1995; Souza et al. 2014). Results of a source rock oil play from the Middle East are presented along with recommendations on removing the effects of Tmax suppression to achieve a representative maturity assessment.
Increased Oil Recovery by Application of Plasma Pulse Treatment
Authors: Pashchenko A. F. , Ageev N. P. 
Published: November 2016

Abstract
Advanced technology of increased hydrocarbons recovery – Plasma Pulse Treatment (PPT) is presented. The explanation of physical impact on the reservoir is given. Examples of laboratory studies and field-testing observed.
The physical bases of the PPT are periodic pulses of equal strength, spaced with equal time intervals by discharge current passing through a metal conductor. Shock wave, formed by the explosion of conductor, is propagating radially with supersonic speed, gets out through the perforation holes and provides an elastic compressive and tensile impact on the media. Low frequency waves, propagating deep into reservoir, contribute to the development and formation of new cracks, as well as the transformation of sub-capillary pores into capillary, causing the liquid moves from stagnant zones and channels to the zone of active drainage.
The paper presents the description of the physics of a process as well as some calculations and estimates of observed technical parameters. Some estimates and calculations, given in the paper, are based on the principles of nonlinear physics and fluid dynamics.
Laboratory studies confirmed substantial changes after PPT application both in oil samples (resulting in viscosity reduction) and core samples (increase of permeability).
Microseismic studies, carried out on the field, registered the propagation of waves, created by PPT, on a distance of over 1.3 kilometers away from a treated well.
Number of well studies both production and injection ones is presented, showing the long lasting effect of treatment. The overall analysis of over 300 treated wells is given, proving the high efficiency of Plasma pulse technology. Technology, presented and described in the paper, allows increasing the productivity of hydrocarbons wells and involving the reserves of residual and unrecoverable oil into production.
Minimizing Cost of the Learning Curve for NOCs in Unconventional Delineation and Development
Authors: Walser Doug , Ranjan Priyesh 
Published: November 2016

Abstract
During the previous 14 years, North American unconventional reserve delineation activities have resulted in hundreds of billions of dollars in capital spending. Development of the accompanying defined reserves has generally been a recent occurrence; in most established plays, the typical wellbore has been associated with field development rather than delineation.
Approximately 102,000 horizontal wells have been drilled and completed in North America since 1990, at an industry cost of approximately USD 750 billion. However, there is a clear trend toward continuous improvement in both process and production response. Much of the learning curve has been based on trial-and-error (T&E) activities, rather than the deliberate acceptance and integration of upfront measurements with the application of physical realities and rigorous peer-reviewed algorithms, concepts, and practices.
During the early history of hydrocarbon extraction, operators experimented with various vertical well drilling and completion (D&C) processes to maximize production and optimize net present value (NPV). Given the steep learning curve that the North American industry has experienced and the significant D&C capital cost of a single unconventional well, it is no longer prudent for national oil companies (NOCs) outside North America to repeat the pattern of historical experimentation to achieve equivalent (or better) efficiencies and results.
This paper offers a number of suggestions and concepts that can be applied to dramatically shorten the learning curve and minimize capital expenditures associated with efficient extraction of ultralow-permeability hydrocarbon reserves. North American parameters that have clearly impacted performance (parallel lateral spacing, fracture spacing along a lateral, total exposed conductive fracture surface area, decreasing proppant diameter, lateral length, etc.) are examined. The quantitative value of applying rigorous reservoir modeling, intensive study of historical practices, and upfront measurements, such as far-field fracture mapping, near-wellbore (NWB) production flow-splitting, and long-term diagnostic shut-in testing, is then estimated by examining the cost of error in delineating and developing a given acreage position.