bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using Innovative Surface Mounted Technology to Boost Production from Low Pressure Oil Wells and Revive Dead Wells Without any Well Intervention
Authors: Peeran Syed M , Beg Najam , Anazi Rayid , Ajmi Shaleh 
Published: November 2016

Abstract
Innovative Velocity SpoolTM (Surface Jet Pump) technology combined with novel compact separation was tested at a remote onshore wellhead location in Saudi Arabia to see if it could increase multi-phase production from low pressure oil wells that were already producing and revive wells that were backed out/not flowing.
The Velocity Spool (VS) is a passive device which utilises often wasted fluid energy (via a choke) from a high pressure (HP) well to reduce the back-pressure of a low pressure (LP) well and boost its' flow to the production manifold. For the VS to work efficiently on multi-phase oil wells, a compact in-line separator is installed upstream to bulk separate the gas and liquid fluids.
For this trial, one of Caltec's patented VS multiphase skids was installed at an onshore wellhead location and connected to existing HP and LP wells. Production from both wells was diverted to the VS to test its effectiveness. The trial tests lasted 3 months.
Results from the first set of tests showed that the VS boosted production from an LP oil well that was already flowing by an additional average of 400 bbls/d with a corresponding wellhead pressure reduction of 45 psi. Results from the second set of tests showed that the VS revived a dead well that had not been flowing since 2004 and made it flow at an average rate of 1100 bbl/d with a backpressure pressure reduction ranging from 54 to 27 psi. Prior to the trial, several attempts had been made to bring this dead well back into production using other methods but these had not been successful. The results showed conclusively that the VS was very effective in boosting production from LP oil wells using passive surface mounted equipment and avoiding any well intervention. The production gain was achieved by lowering the FHWP of the well and the amount of gain was dependent on the productivity index of the well.
The advantages that the VS offers over conventional technologies such as Multi-phase pumps and ESPs are several: it is tolerant to variations in flow conditions, gas volume fractions (GVF) and associated slugging (without affecting performance), it is surface mounted (so well intervention is not required), low cost, easy to deploy, has no moving parts, consumes zero fuel gas/electrical power and uses already available surplus energy.
This paper reports the trial results and discusses the use of Velocity Spools as an alternative to other boosting methods for oil production. The design and operational criteria of the VS are also highlighted.
The Effects and Modelling of Stress in Hydraulically Fractured Tight Reservoirs
Authors: Bhinde T. , Todman S. 
Published: November 2016

Abstract
Rock stress changes strongly impact well drilling schedules, well placement, fracture design and fluid production in unconventional reservoirs. The objectives of this work are to understand and quantify the effects of stress changes caused by production and fracture stimulation in tight reservoir (shale oil/gas) plays. The implications of stress changes on well drilling (timing), interference between wells due to stresses (well placement) and fracture design (number, placement and timing) are investigated in this work.
Numerical simulation models that integrate several physical effects have been used to achieve these objectives. This integration includes the modelling of fluid flow for reservoir pressure and temperature calculations, full field geomechanical stress, fracture initiation and propagation, rock failure, along with detailed wellbore models.
The work shows that the creation of a single fracture on a well strongly affects the formation of a nearby fracture on the same well. The entire process of multistage hydraulic fracturing can be simulated by integrating the above-mentioned physics in a single model. The results can be used for fracture placement and surface pump duty estimates. The fracture creation model can also be used to estimate the extent of stimulated rock volumes in the reservoir. Stress interference effects between wells can also be investigated using full field modelling.
Furthermore, the closure of natural fractures within stimulated volumes in the reservoir, which reduces permeability affecting future production, can be estimated using full field geomechanics modelling.
The far field effects of stress in unconventional plays show that, although the wells are in pressure isolation, there are strong stress interference effects between wells. The models can be used to generate guidelines on well drilling schedules, well placement, and fracture design and location in such systems.
Several papers exist in the literature on different physical effects studied in isolation within the context of geomechanics in unconventional reservoirs. Importantly, this work integrates the different physical effects in a single model. The work introduces novel considerations on the importance of drilling schedules, well placement and fracture design in unconventional plays.
Go Green - Save Our Earth: GT Low Emissions Combustion Conversion
Authors: Mahmood Tariq , Al Kazeeri Ahmed Hamad , El-Abyouki Mohammed 
Published: November 2016

Abstract
Targeting "Go Green - Safe Our Earth", a state of the art Low Emissions Combustion conversion project was embarked on Habshan Power Generation Berth 80G-105 Frame-6B Gas Turbine.
In line with GASCO emissions reduction strategy, LEC/DLN conversion study of a Habshan power generation berth 80G-105 Frame-6B Gas Turbine was launched as a Pilot. Accordingly, a detailed scope of work was prepared to initiate the retrofit on a turnkey basis. The thorough design review, HAZOP and SIL studies have produced a robust system which includes: LEC Combustion Components, New Fuel Gas Heater and Filter Skids, New Inlet Bleed Heat System, New Fuel Gas Splitter Valve Skid, Flame Detectors and Igniters Replacement and Modifications of the Control System.
With successful implementation of LEC conversion, first retrofit within ADNOC OPCOs, NOx has been reduced from 161 ppmvd to 9 ppmvd (94% Reduction, 575 Tons/Year) whereas CO from 127 ppmvd to 05 ppmvd (96% reduction, 283 Tons/Year). Above reduced emission levels are well below the boundary set by Abu Dhabi Environment Agency for NOx & CO upto 35 & 400 ppmvd respectively. In addition to the remarkable reduction in NOx/CO emissions, the new installed LEC combustion components are of extended life, therefore eliminating the existing combustion inspection every 12,000 Hours saving 10 days shutdowns every one life cycle (48,000-60,000 Hours).
The LEC conversion project presents a unique example of encompassing an innovative approach to achieve tangible environment protection through using improved technology. Further to the implementation of the project, the rewards thus achieved with clean environment are perpetual.
Reservoir Fluid Identification – A Case Study of a Near Critical Fluid From Low Permeability Exploratory Reservoir
Authors: Amjad Kashif , Ahsan Syed Asif , Sultan Mir Asif , Hegazy Gehad Mahmoud 
Published: November 2016

Abstract
Fluid identification is an important step in reservoir characterization and hydrocarbon volume estimation of an exploratory target. Volatile oil / Gas condensate reservoirs are well known for complex behavior due to near critical fluid nature. Objective of this study was to identify fluid nature in a low permeability reservoir where a single phase PVT fluid could not be obtained. This study describes a carefully designed analytical and interpretive workflow that utilized analyses of the separator samples and integration of the data from G&G sources to discern fluid nature.
This paper describes the methodology of identifying fluid nature of collected separator samples from ADCO's exploratory reservoir in a field that has potential to add significant reserves to its portfolio. Due to high pressure encountered during drilling of the exploration target reservoir, Wireline Formation Tester (WFT) pressure gradient and bottom-hole samples were not acquired. Wireline logs were acquired after several weeks and consequently did not help in distinguishing the hydrocarbon type. Production test conducted across the 6 ft thick top layer resulted in 49° API oil with GOR varying from 3000 – 4000 scf/bbl. Three (03) sets of oil and gas separator samples were acquired and physical recombination was performed in the PVT laboratory at reservoir conditions using two different GOR values. Composition analysis of separator liquid was also performed and compared to the same reservoir in analogue fields at comparable depth.
Physical recombination at GOR values of 3000 and 3759 scf/stb exhibited oil and gas-condensate behavior at respective GORs. Composition analysis of separator liquid also indicated significant amount of heavy components (C7+: 65.5% and C12+: 23.6%). Reservoir compositional data was plotted and compared to similar oil / gas-condensate reservoirs from nearby fields. Fluid was identified to be of volatile nature based on PVT study as bubble and dew points pressures were very close in recombined samples. The mud log data showed high total gas reading of 17% in the zone of interest. An assessment of hydrocarbon phase at this high total gas reading based on Wetness (Wh) and Balance (Bh) ratios already indicates presence of light oil. Further PVT work including an attempt to acquire WFT sampling of a single phase fluid is recommended in appraisal wells to thoroughly understand the near critical hydrocarbon phase in the reservoir of interest.
Well Integrity Assessment Using Video Camera Technology - Case Histories
Authors: Al-Zain Ahmed , Al-Mulhim Abdallah , Al-Subaie Fehead , Al-Jandal Ahmed , Al-Mulhem Abdul-Aziz , Al-Hindas Omar 
Published: November 2016

Abstract
Video technology has been used worldwide in various applications, including situations that require diagnosis and evaluation. Advances in video equipment have led to the development of downhole video cameras that are capable of working in the harsh environments encountered in the upstream oil and gas industries.
With the advent of video technology in the oil and gas industries, unique opportunities have been captured to enable efficient and effective means of what is really happening downhole in wells. Video cameras are deployed downhole via either wireline, coiled tubing or drill pipe to inspect well bores. Cameras can be run with down view, side view or both. Common applications include imaging and inspection of wellhead hardware, tubular hardware, fluid movement, leakage, scale deposits, fills, dropped objects, fishing, milling etc. With latest advancements in the deployment methodology, video technology as a downhole diagnostic tool provides the industry with invaluable and useful services.
The video camera assembly connected to a tool string consists of two color video cameras for down and side views. The down-view camera is supported with a light head, which uses LED technology combined with an optimized lens to give color pictures.
The side-view camera has also its own LED lights and a lens with a focal length from 1″ to 8″, providing reasonable views in 2 3/8″ tubing to 21″ tubulars. Rotation of the side-view camera is facilitated by the E-line motor, which is controlled from the surface with side indicator to show where the camera is positioned.
Deviation, high side indicator and internal temperature are digitally transmitted to a surface laptop, providing essential information when viewing images. Additional information such as date, time, running speed, depth, light intensity, and other data could be added to the videos or pictures.
This paper will review applications of video camera in a giant field in Saudi Arabia. Case histories recorded by the video camera will be presented and analyzed to illustrate the usage and benefits of the system in relation to well integrity. It will also highlight findings and remedial actions to restore well integrity.
Silicone Rubber Drill Riser: Handle Drastic Conditions at Reduced Costs
Authors: Kumar Shashank , Jain Udai , Vaish Pranav 
Published: November 2016

Abstract
Risers are considered to be the most critical product in offshore pipeline development taking into account the dynamic loads and sour service conditions they need to withstand. The idea aims at providing a design where the riser is equipped with shock absorbent and thermally insulating material rather than increasing the steel layers around it (conventional method) for making it withstand notorious conditions combined with increased lifetime.
Modification in the existing riser design includes reduction in the steel thickness of the riser, addition of an external high carbon steel casing (of larger diameter) around the outermost layer of the riser and accommodation of a filler material between the reduced outermost steel layer and the added outer steel casing. The filler material used is silicone rubber blended with microballoons (hollow glass microspheres usually of diameter 100 nm – 5 mm), which is non-reactive, corrosion resistant, stable to extreme environments, resistant to high pressure, high temperature and shear force. This will bring to you a riser that can withstand very high pressure and temperature.
A brief comparison between silicone rubber riser and conventional steel riser is presented in the paper. The economics of the method, and the method itself, is compared to the current riser design. The proposed riser design's cost effectiveness lies in the fact that the layers of the riser being protected by highly resistant silicone-rubber are saved from outer corrosion and other damaging factors, therefore increasing their life and providing reusability. Also, the microballoons used to blend the silicone rubber are produced as waste product in coal fired power stations, hence prove to be economical.
The novelty lies in the fact that the proposed riser design provides enhanced properties when compared to the conventional drill riser and also won't add up being a burden on any companies' economics provided its cost effectiveness.
Keeping Oil & Gas EPC Major Projects Under Control: Strategic & Innovative Project Management Practices
Authors: Al-Hajji Hamad , Khan Shehzad 
Published: November 2016

Abstract
The Petroleum industry requires construction and maintenance of ‘upstream’ and ‘downstream’ facilities. Kuwait Oil Company is dealing with exploration and production of crude oil & natural gas. EPC projects plays an important role in generation of new physical facilities to maintain or enhance production. Project management has developed tremendously over time due to evolvement of numerous strategies to deal with construction activities. Schedule and Budget are the two major concerns required to be optimized during execution. Therefore, a very effective & efficient project management system is needed and has to be framed to deal with the major capital construction projects. In effect, help organization make impact on country's economy.
The objective of this paper is to explore few successful in-house projects to find out what went well to identify and analyze key techniques employed to mitigate causes of delay in order to recommend strategic and innovative methods to realize maximum benefits by completing the project on time and within budget. This paper examines various project control methods covering project constraints for formulating strategies, planning, budgeting, procedures, processes, performance measurement, etc. contributing to the successes of acclaimed projects.
The paper has provided advisory-notes on the real-time innovative methods for executing projects, which helps in making the projects more process oriented. The other critical factors, are the best practices to simplify project management techniques and making them more explicit. By applying these innovative approaches, most of the tacit knowledge that is used get converted into an explicit knowledge through proactive participation.
The study has provided an insight in some novel innovative and strategic project management techniques leading to saving in time and cost by overcoming causes of delay and highlighting suitable measures to overcome bottlenecks during project life cycle. Some proven state-of-the-art approaches have been developed in-house by KOC to assure project performance and uphold the Company's reputation and corporate image. Deploying a combination of these methods as a minimum in project execution has shown very fruitful results, which in turn has helped KOC in achieving its strategic objectives.
Subduing Harmful Exposure of BTEX by Improving Facility and Practices
Authors: Veerakumar Ukkirapandian , Al Shaali Saud Jamal , Abbas Ahmad 
Published: November 2016

Abstract

Objective
The objective of this project is to survey the current exposure level of BTEX to laboratory technicians by measuring intake and their metabolites in urine sample. It is also to take appropriate actions to control their exposure through improvement in facility, practices and corrective actions.

Methods, Procedures and process
Occupational health survey on technicians performing sampling and analysis of crude oil, condensate, paraffinic naphtha etc. was carried out every year by a competent external agency. The BTEX vapors were absorbed in a passive sampler for 8 hours held close in the breathing zone of technicians. The absorbed components were extracted and analyzed using chromatograph for benzene, toluene, ethylbenzene and xylene. Their metabolites were determined by collecting pre/post urine samples after extended hours of exposure.

Results, observations and conclusions
In 2010 BTEX were below the threshold and detection limits in 4 cases out of 5. The BTEX metabolites were below detection limit (DL) and Threshold Limit value (TLV). In Oct 2012, the survey indicated abnormal and higher BTEX values; particularly Toluene was 120 mg/m3 as against the TLV of 75 mg/m3. Several steps were taken which included training, awareness of technicians, good laboratory practices, personal protective equipment and improved exhaust system and ventilation. The air intake velocity of fume hoods, HVAC system, the ambient temperature etc. were inspected and monitored. Additional fume hood was installed to extract vapors. The activated carbon filters of all 19 air extraction blowers were replaced in Sep-2013 to ensure increase in fume hood air velocity and for complete absorption of BTEX in these filters so that there is no air pollution.
A special type of face mask (Model 3M 9922) was introduced which prevents direct inhalation of volatiles. BTEX exposure was minimized by improving the performance of fume hoods, extraction system, exhaust bowers and HVAC Units. Training of technicians and their awareness on release of BTEX and ways of minimizing their exposure helped us to implement a good laboratory practice thereby minimizing exposure. Strict adherence to safety procedures and using appropriate personal protective equipment reduces inhalation of BTEX. Improvement in the exhaust filters minimized air pollution. The subsequent surveys indicated that the working place is well protected against release of BTEX and there is no risk to health of the staff. By the whole process we could meet both local and international legislation on BTEX emissions.

Novel / additive information
This significant improvement can be shared with ADNOC group of companies having similar work place hazards. This can be considered as an achievement and operational excellence towards ADGAS commitment in safeguarding the safety of our employees and looking for improving the work environment.
Implementation of an Early Drilling Problem Detection System with Dynamic Look-Ahead Simulations to Assist Drilling Decisions on a Shallow ERD Well in the Barents Sea
Authors: Kucs Richard , Trauner Stephan , Abrahamsen Egill , Hollinger Gerald 
Published: November 2016

Abstract
In the petroleum industry, software systems designed to monitor real-time drilling parameters are constantly evolving, with the aim of providing improved capabilities in the early detection of dysfunctions during the construction of wells. When optimally applied and embedded within a drilling team, such software systems have been proven to be of great benefit to the operation by helping to avoid major drilling problems. The trust in and the implementation of the information provided by such software are crucial factors of success, and herein lay the biggest challenge.
This paper investigates the application of a cutting-edge, early drilling problem detection system for the drilling of a complex, shallow horizontal exploration well. It determines if the use of the system was successful and looks at improvements that can be made to the system for future operations. The study was performed by a combination of reviews of the software output, interviews with key personnel involved, experience's from other cases, and theoretical knowledge.
The case well was drilled offshore Norway in the Barents Sea, with a rig contracted solely for this well. The operator employed a permanent drilling team in the local office in Stavanger, with key personnel located on the rig. The company providing the early drilling problem detection system had an engineer at the rig site as part of the drilling team. The system installation was coordinated by the local office while being supported in setup and organizational matters by the well engineering global support team at the operator's head office in Vienna. The implemented system simulated the physics in the well bore to provide early identification of drilling problems, and produced dynamic look-ahead simulations to assist drilling decisions. Key factors such as communication patterns, when and which functionalities of the system were used, how the results were fed back into the operational decision making, the organizational set up, and the physical placement of the various personnel and the technology used will be investigated. Additionally, the paper will look at the learnings and potentials for future implementations of such a system.
New Saturation Functions for Carbonate Reservoirs TZs based on Fundamental Petrophysical Properties
Authors: Raheem Oriyomi N. , Belhaj Hadi 
Published: November 2016

Abstract
In the present study a core analysis program including NMR measurements were performed to get a better petrophysical characterization of carbonate reservoir transition zone in the Abu Dhabi region. The results reveal three distinct rock types with average NMR-T2 cutoffs of 292 ms, 164 ms and 63 ms for the topmost, middle and lowermost samples of the reservoir respectively. Electrical resistivity and capillary pressure-water saturation were also measured at ambient and reservoir (2500 psi and 85 °C) conditions using a DCI Pc-RI system mimicking drainage and imbibition to investigate the hysteresis and variation in saturation exponent.
It was found that the cementation exponent increases from 1.9 to 2.3 under overburden conditions and decreases in a stepwise manner during reduction of overburden, but not to the initial value due to hysteresis. This implies that the electrical parameters at ambient condition would lead to underestimation of water saturation. The saturation exponents estimated during drainage and spontaneous imbibition at reservoir conditions range from 1.6 – 7.5 for the different rock types tested in this study. New saturation functions were developed for each rock type from the measured electrical parameters at reservoir conditions by using the modified Archie’s and Skelt Harrison’s equation for the transition zone of this carbonate reservoir. The outcomes of the present study lead to a correction of the field resistivity log data that, overestimate the water saturation and hence predictions of saturation distributions, mobility and original oil in place.