bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evolution & Acquisition of the World's Largest OBC 3D/4C Seismic Survey
Authors: Mercado Gary , Nakayama Shotaro , Benson Mark , Belaid Kamal , Al-Hendi Ahmed , Lecoq Thierry , Bourdarot Gilles 
Published: November 2015

Abstract
An Ocean Bottom Cable (OBC) 3D/4C seismic survey covering 2730 square kilometers and spanning 23 months has been undertaken by ADMA-OPCO. This survey covers 2 offshore congested producing fields, plus several exploration areas currently planned for development in the near future. This large acquisition when coupled with two previously acquired 3D OBC surveys (in 2000 and 2007) offers 4580 square kilometers of continuous 3D OBC converage.
Coordination and intensive communications between 6 shareholders, 14 ADMA-OPCO divisions and 4 governmental agencies were required to facilitate this survey. The initial survey design (used for 2 months) used Distance Separated Simultaneous Source (DS3) acquisition but was revised to Managed Source and Spread (MSS) acquisition for improved fold, offset and acquisition efficiency. During the course of survey acquisition, 3 different test data sets were also acquired for technical analysis. A short history on the feasibility and complicated process leading up to the start of the survey will be offered, as well as samples of the onboard processing from the various areas will be presented.
This survey was acquired in a little over half the time of previous OBC surveys in offshore Abu Dhabi. The data, based on limited onboard fast processing, is of high quality and illuminates deeper gas bearing structure and stratigraphy. Formal onshore processing has begun and promises excellent results.
This innovative acquisition has provided more efficient data acquisition saving time and money, reduced HSE exposure in busy fields and will in conjunction with previous surveys provided one of the largest continuous offshore 3D datasets in the Arabian Gulf.
Energy Integration Opportunities in GOSPs Through Gas Conditioning
Authors: Al-Zahrani Talal , Soliman Mohamed 
Published: November 2015

ABSTRACT
This study evaluates different energy integration opportunities within a typical gas-oil separation plant (GOSP) to simultaneously achieve the export gas specifications and provide the wet crude handling heating requirements without the need for external energy consumption. The subject GOSP is designed to gather and condition the associated gas to a water content specification (spec) of 7 lb/million standard cubic feet (MMscf) and hydrocarbons (HC) dew point spec of 80 °F at plant export pressure.
Several approaches were studied through process simulation to utilize the available cold and/or high- pressure streams for providing the dew point control cooling requirement of the associated gas without using a refrigeration system, which is the backbone of dew point control units (DPCU) in Saudi Aramco and worldwide. In addition, this integration eliminates the crude dehydration/desalting steam requirements on the other side. The following options were evaluated to achieve the objectives: Heat exchange between hot compressed gas and cold crude received from subsea pipeline.Further gas cooling by HC condensates (Energy recovery of condensates pressure drop).Export gas cooling and re-compression through turbo-expander.
Technical evaluation showed that all options achieved the gas conditioning objectives with some limitations in Option 1. Eventually, Option 2 was selected as the optimum choice that meets all required export specifications in both summer and winter operations. Therefore, the existing propane refrigeration system could be eliminated as well as the need for steam consumption in the crude side, resulting in total power savings of 10 MW.
How the Petroleum Industry can Learn from the Ebola Crisis of 2014
Authors: Willemse Andre 
Published: November 2015

Abstract

Objectives/Scope
This session will review the Ebola outbreak from the viewpoint of an onshore and offshore petroleum operator. It will provide insight into the real threats the outbreak presented by looking past the media hype and diving into the real organisational effects of the outbreak. The presenter will show how, though contained to parts of West Africa, the Ebola crisis established a new model for medical risk management that can be applied the world over.

Methods, Procedures, Process
The presenter was on the ground in West Africa during the Ebola outbreak assisting various organisations, including the petroleum industry, to navigate the medical risks while helping to ensure minimal disruption to employee health or operations. Through this first-hand experience, the presenter will review the key takeaways from the outbreak to highlight how major infectious diseases, such as Ebola, cannot always be easily managed through traditional HSE protocols. It will establish key variables of medical risk and discuss how HSE and medical management must be part of every company's overall operational structure.

Results, Observations, Conclusions
The Ebola outbreak caused major disruptions to all industries operating in or around West Africa. Earlier, there were confusion and grave misconceptions about the extent of the outbreak which led to many petroleum operators unprepared for how to best manage the medical threats to their employees. Traditional models of HSE and infectious disease management did not easily apply to the developing threats. As organisations were caught off guard, they were forced to adapt to a rapidly changing situation as the outbreak spread. This medical incident quickly became a threat to all operations as basic infrastructure degraded, resources became unreliable and security threats increased. Those organisations who took a preventive and holistic approach to HSE management were better able to respond and ensure minimal impact to their operations.

Novel/Additive Information
The Ebola crisis of 2014 was one of the worst infectious disease outbreaks in recent history. It also occurred in a region with endemic medical risks and poor medical infrastructure. These two factors make it an important learning exercise for the global petroleum community. The presenter's first-hand experience will provide substantial insight into the long-term effects of the Ebola crisis and how organisations can learn from this event and benefit from implementing their own mitigation strategies.
From Exploration to Production in 4 Years: Industry Collaboration Leading to Accelerated Learning Curve for Large Tight Gas Project in the Sultanate of Oman
Authors: Al Riyami Qassim , Briner Andreas , Elliott David , Judd Tobias , Nadezhdin Sergey , Gurmen Nihat , Batmaz Taner 
Published: November 2015

Abstract
A large, strategically important unconventional (tight) gas project in the Sultanate of Oman advanced from the exploration stage with one discovery well to the pilot and development stages over 4 years. Project challenges in the first 2 years of exploration were poor initial success in both fracturing treatment placement and subsequent productivity and an ever-expanding scope of work in a demanding environment with limited resources. To address these challenges, the focus was shifted from routine delivery to an integrated approach and a strategy that included defined activity timelines, key performance indicators aligning with different stakeholders, and process reviews. Technology deployment and improved operations with allocated fracturing equipment spread gave flexibility to this new efficiency model. Integrated technology trials included cased and openhole completions; different well types; and several rock and core mechanical tests, such as reservoir coring, openhole stress testing, sonic measurements, and continuous unconfined compressive strength measurements. It also incorporated abrasive perforating, various fracturing treatment type designs, and advanced evaluation techniques such as microseismic monitoring, three-phase flow metering, tracers, and others. These technologies were implemented in a fast and efficient manner owing to strong collaboration between a dedicated Petroleum Development Oman (PDO) subsurface team and the service provider expertise. Personnel embedded in the exploration team greatly helped with linking to proper resources within the suppliers. An embedded engineer provided immediate technical and logistical support to the team. The improved process involved multiwell fracturing, a test campaign, and evaluation of individual zones. Finally, gaps and areas for improvement going forward were identified. Over the 4 years, with implementation of the new technology and strategy, the success rate of fracture placement and zonal evaluation increased from the low initial success of less than 50% to 100%; the improvement was particularly evident in the extremely tight lower intervals of the reservoir.
Custom-Designed Water-Based Polymeric Reservoir Drill-In Fluid leads to Successful Drilling, Coring and Logging Operations in a High Temperature, High H2S Environment; a Case Study
Authors: Walters G. A. , Elenbaas M. J. , Richardson D. J. , Rosener A. , Hussein M. , Anez M. J. 
Published: November 2015

Abstract
As a part of an appraisal campaign within a sour gas and condensate field in Abu Dhabi, an extensive coring, logging and testing program was planned for the target reservoir. One of the challenges was to design and implement a suitable water-based polymeric reservoir drill-in fluid (WB-RDF). Optimum lubricity and rheological properties were essential in this 8–1/2" section being drilled through the reservoir at approx. 45° inclination. Another key element of the design process was to ensure that the fluid remained stable during extended periods of coring and logging while being exposed to high levels of H2S and bottom hole temperatures of 288 degF.
Extensive laboratory testing was undertaken where the behaviour of the RDF was analysed after extended exposure to temperatures and pressures representative of the bottom hole conditions in the well. The mud formulation consisted of polymeric additives, a polymeric alkaline temperature stabiliser and an ammonium bisulfite oxygen and triazine based H2S scavenger. A graded calcium carbonate was included for bridging purposes, aiming to minimse the fluid invasion into the formation. The rheological and fluid loss parameters and stability of RDF were verified during extended periods of static conditions.
Specific fluid management procedures were implemented to ensure that the appropriate concentrations of H2S scavenger and temperature stabilizer were maintained in the mud system at all times. The Garrett Gas Train and its testing protocol was used to monitor H2S levels which, converts the soluble sulfides, bisulfides, H2S into gases which, then seperates the gas from the liquid, thereby eliminating effects of the liquid on the drager detection tube. It must be noted that this test converts all soluble sulfides to H2S and is therefore not specific to H2S alone and this test is a quantative analysis of sulfides. The monitoring process applied was during circulation. The GGT was ran frequently on bottoms up samples and specifically during the periods of circulation where the fluid had remained static due to extended logging.
Other fluid parameters, pH and alkalinity measurements were also monitored with basic mass balance and volumetric evaluations taken into consideration.
One of the key processes was the spotting of specifically formulated pills across the open hole prior to tripping. The risk of polymer degredation is increased during extended periods without circulation and the consequent elevation of bottom hole temperature.
This paper has been prepared to summarise the upfront fluid design and associated laboratory evaluation work performed to ensure fluid stability was maintained in challenging bottom hole conditions. An overview is provided of the fluids management procedures implemented during drilling, coring and logging to ensure a safe and successful operation.
Paradigm Shift from Seismic Array to S4 in Acquisition and Processing; Case Study of Onshore 3D Seismic, Abu Dhabi, UAE
Authors: Mahgoub Mohamed , Seo Youngtak , Dhafra Al , Busanello Gabriele , Roig Carlos , Glushchenko Anna 
Published: November 2015

Summary
Single-sensor land acquisition technology pioneer's the approach of an integrated acquisition and data processing system to provide solutions in challenging environments. From fast-moving, low-density exploration surveys to wide-azimuth, broad bandwidth, point-source/point-receiver reservoir surveys.
Acquiring seismic data using conventional source and receiver arrays in areas with large elevation variations, from Sabkha to gravel plain to high sand dunes causes fluctuations in the signal arrival time, partial cancellation of the signal, intra-array statics and seismic noise aliasing issues. The use of S4 (Single Source Single Sensor) to acquire seismic data in the area of study helped to resolve all previous field acquisition issues and delivered outstanding 3D seismic data.
Novel Low-Solids Shear-Dependent Cement System Used to Cure Severe Lost Circulation while Drilling: A Case History
Authors: Urdaneta J. A. , Ravi K. , Gonzalez F. E. , Viera J. M. , Marinkovi R. Liaño , Castillo O. Pedrazas 
Published: November 2015

Abstract
Lost circulation in the oil industry is a recurrent and costly challenge, especially in mature fields or weak fracture-gradient zones. Incidents can result in partial to total losses in a variety of formations, including highly permeable, fractured, or cavernous types. In most cases, the first treatment options include using gel or mud pills with lost circulation materials (LCMs). However, this and other solutions currently in the market might not fix severe or total losses.
This paper presents a low-solids lost circulation solution that develops rapid gel strength when the shear rate decreases. The gel strength buildup is based on polymers and nanomaterials in the fluid system. In situations where the vein or cavernous zones are large, traditional solutions tend to be ineffective. In such cases, a shear-dependent fluid system can be used that develops gel strength as it enters the larger-flow-area lost circulation zone. This helps prevent the fluid from continuously flowing into the zone. Once the gel strength has developed, the system develops nominal compressive strength to adhere to the formation, helping prevent displacement during subsequent well operations.
A mature production field in Santa Cruz, Bolivia presented significant challenges during drilling operations. The low fracture gradient and pressurized gas formation created a narrow operational window, increasing the probability of lost circulation because of the mud density required to avoid fluid influx during drilling. In this scenario, LCMs would not stop fluid losses and were limited to pumping through the bottomhole assembly (BHA). The low-solids lost circulation solution was pumped through the drill bit. Having low solids and low rheology under shear, it can be easily pumped through the drill bit without having to pull out of the hole (POOH).
The losses were stopped by using this low-solids shear-dependent (LSSD) fluid system. Subsequently, the primary cementing was performed successfully, and effective zonal isolation was achieved. This helped eliminate non-productive time (NPT) in gas wells in Bolivia.
This paper presents a successful methodology, lessons learned, and engineering design to cure lost circulation during drilling operations by pumping a novel LSSD solution through the drill bit. The fluid system contains a low amount of solids; hence, it can be pumped through the drill bit, and the fluid characteristics are such that it will plug trouble zones effectively.
A Case History of Nitrogen Injection Monitoring in Rich Recycled Gas Condensate Reservoir, Onshore Gas Field, Abu Dhabi, UAE
Authors: Hamza Hamza M. , Al Suwaidi Mahmood , Al Jeelani Omar , Al Yafei Arafat , Basioni Mahmoud , Al Yaqoubi Khaled , Kumar Arun 
Published: November 2015

Abstract
A mixture of Nitrogen and hydrocarbon gas was used as a cycling gas in a large rich gas condensate reservoir to maintain reservoir pressure and thus prevent condensate drop-out due to pressure decrease below the dew point pressure. The objective of using Nitrogen gas is to partially replace some of hydrocarbon injection gas, which has a high demand for Abu Dhabi domestic consumption.
This paper presents the plan, implementation, results and analysis of an intensive reservoir monitoring program, which was conducted to monitor the Nitrogen injection and production. Additionally, the paper discusses lessons learned from the Nitrogen injection, inferences reached, and corrective actions taken.
The Nitrogen injection was started as a Mixed Case (MC) injection, where a mixture of Nitrogen (~20%) and hydrocarbon gas (~80%) was injected in all existing injectors across the entire reservoir for a period of three years. The plan was to stop the MC injection and apply a Pure Case injection (PC), which consists of injecting only pure Nitrogen in the North West area of the reservoir. The objective of the PC injection is to localize the Nitrogen injection to be able to apply Nitrogen removal technology in a specific part of the existing surface facilities whenever high Nitrogen production is reached.
Monitoring the Nitrogen production relies mainly on an intensive gas composition sampling and analysis, which have been conducted quarterly for all gas producers, in addition to other surveillance activities of the intensive reservoir monitoring program. The Nitrogen monitoring results and analysis of the MC injection showed Nitrogen breakthrough in many wells with increasing Nitrogen production trends. Different analytical techniques were applied to evaluate and predict the Nitrogen breakthroughs. Due to the unavailability of surface Nitrogen removal facilities and the increase in Nitrogen production during the MC injection, a Nitrogen risk assessment study supported a recommendation to stop the MC injection and continue cycling with dry hydrocarbon gas only as before. Also, it was decided to delay the planned PC injection for more evaluations and studies.
Acid Aided Regeneration in Amine Treating: How Effective is it?
Authors: Klinkenbijl Jeanine , Brok Theo , Critchfield Jim , Valenzuela Diego , Lee Danmi 
Published: November 2015

The development of more complex energy sources is increasing to meet the growing demand for more energy. Such gas resources may be more contaminated, more complex, more costly, and contain more CO2 and H2S. At the same time, tighter environmental and product specifications necessitate smarter gas processing. This needs to be achieved by stretching current processes and developing reliable new technologies to effectively address the challenges of managing complex gases.
One area of gas processing that is well established is Acid Aided Regeneration (AAR) technology: the use of acids to reduce the regeneration steam of amine treating units has been applied since the 1960s, and is nowadays often referred to as a Formulated amine. Or, achieve a lower specification in the treated gas, due to a lower leanness in the solvent when the regeneration heat is kept constant, and thereby reduce environmental (CO2 and/or SO2) emissions.
Shell has carried out an extensive study on the use and misuse of AAR, focusing on the actual effects in operation and comparing unit performance with results of process simulation in the presence of acids in an amine solvent.
The operational effects observed are explained and general guidelines for application discussed. Although the focus of the application is on low pressure selective design (Tail Gas Treating Units), the main effects for high pressure application are also addressed in the study. In the paper the basis for the Shells AAR technology is described: Detailed analysis of process performance (both analytical solvent analysis and actual plant performance data) in aqueous amine treating units in a wide variety of applications. This gives good and consistent insight in the qualitative and quantitative results of acid addition to amine solvents and measured contaminant removal.A theoretical discussion on the acid effects in an amine solution, focusing on the energy for regeneration of the amine, as well as the option to meet a lower contaminant specification with a constant regeneration energy requirement by the addition of an acid to the amine solution.
Starving Bacteria to Stop H2S Generation
Authors: Subramanian T. S. , Adel Khalid , Awadhi Ibrahim Al 
Published: November 2015

Abstract
Instrument Equipment Shelters (IESs) are important control buildings within Operating Plants, housing critical Instrumentation and Control System (ICS) Panels essential for Plant operations. At one such IES building in one of the GASCO plants, frequent tripping of ICS panels was encountered, without pre-alarm indication, leading to Plant upsets and posing risk to the safe operations of the Plant. Occasionally, smell of H2S was observed. This Paper addresses the measures undertaken to identify the source of generation and diffusion of corrosive agents into the IES building and remedial measures to eliminate this chronic problem.
A detailed study was carried out which included soil and water sample collection and specialized lab testing, collection and testing of electronic cards, discussion with control system Vendors and desktop evaluation of data. Analysis of cards indicated corrosion of electronic components within the panels as the primary reason for the tripping of panels. Corrosion of electronic components was concluded to be mainly due to diffusion of H2S into the building, also as confirmed by Control System Vendors.
Ingress of corrosive agents through air inlets / doors was eliminated as a reason due to absence of any corrosive signs in HVAC air intakes and maintenance of positive air pressure within the building. Extensive investigation and testing of soil indicated presence of High concentration of Sulphate Reducing Bacteria (SRB) in the vicinity of the building. High ground water table containing sulphates, provided nutrition to SRB. The bacteria reduced the sulphates present in ground water to H2S. The H2S thus generated diffused into the building through cable entry sleeves, reaching the area beneath the false flooring on which panels were mounted, and subsequently entering the panels. Presence of conducive temperature and humidity facilitated reaction of H2S with electronic cards, thereby causing corrosion and tripping of panels. The key remedial measures recommended, (1) dewatering the surrounding area and lowering ground water levels to starve the bacteria, rendering it dormant and preventing H2S generation, and (2) sealing of cable entry sleeves to prevent any external gas ingress into the building, have been implemented, resulting in resolving the issue and maintaining the safety and integrity of plant operations.
Tripping of ICS panels due to H2S generation by bacteria present in soil is a unique phenomenon, not commonly encountered in oil and gas plants. In areas where ground water table is high, construction of buildings need to be carefully planned. Geotechnical investigation shall include testing for presence of organic content, sulphates and sulphate reducing bacteria (SRB) in soil and groundwater in addition to conventional tests.