bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Rotating Magnet Ranging System and An Innovative Concept of Heat Recycling in SAGD Operation
Authors: Jin Fu , Shunyuan Zhang , Bingshan Liu , Bo Li , Lisheng Chen 
Published: June 2018

Abstract
As a kind of methodology to develop coalbed methane in China, RMRS (Rotating Magnet Ranging System) has been popular in SAGD operation in recent years. In Liaohe Oilfield SAGD (Steam Assisted Gravity Drainage) is becoming a more and more mature methodology. In a pair of parallel wells high pressure steam is injected into a horizontal well to drain heavy oil into the lower production well. However, not all thermal resources have not been exploited, such as heat of the hot production fluid, flue gas and hot brine separated by the steam-water separator in the boiler.
Trials and researches were finalized on many dual-horizontal wells in Liaohe Oilfield to learn about the present situation and technical capabilities, while thermodynamic models of various types were established and experimental means were applied to analyze thermal distribution and each of the thermal sources previously mentioned. Effects of various media, flow rates and temperatures on thermal utilization and heat deficit rates were studied on the assumption that one ton crude oil was produced per hour.
Waste heat of flue gas may be utilized to help combust air and the thermo-coil may be used as the air preheater, which improves boiler’s heat efficiency. The high temperature production fluid may be used to heat water in the boiler first and then used as the heat source of the absorption heat pump, so that heat is transferred from the low temperature heat source to the high temperature heat source and the low grade heat energy is recycled. As a high grade waste heat, the HPHT brine that is separated from moist steam in the boiler takes up twenty percent of the total water and shall not be only used to heat injected water. Instead, it may be used to achieve flash evaporation. Thus, waste water is heated and distilled water is recycled.
The waste heat recyling model applies thermo-coil air preheaters to recycle flue gas and flash evaporated hot brine to evaporate waste water. Beside, hot production fluid is recycled to heat boiler water. On a basis of the same fuel consumption volume, the recovery rate and marketability of crude oil are both improved.
Selectivizing a Singled Bed Reservoir, A Successfully Application to Increase the Vertical Displacement Efficiency in a Heavy Oil Waterflooding Project
Authors: Solórzano Pedro , Ahmedt Diana , Jaimes Claudia , Henao William , Vega Sandra , Guerrero Cindy , Meza Eliana , León Juan , Dueñas Danuil 
Published: June 2018

Abstract
This paper presents the application of multiple selectives injection zones within a high thickness singled bed heavy oil sand. The results were compared with a single zone completion in the same sand, establishing the differences in several aspects like recovery factor, vertical distribution efficiency, operation styles and completion difficulties.
This approach is based on the application of two methods of water vertical irrigation in a heavy oil sand, first, a singled 300’ zone completion and else, a 3-4 selectives zones completion, separating the equivalent injection in spaces of 60’-100’ thickness each. To route the flow, the packers were located next to thin shale planes most as possible. The objective was use this natural inundation surfaces intentionally as vertical permeability barriers looking forward to this works as a vertical flow controllers beyond wells selectivization, means like flooding separators, inside the heart of reservoir. In injector wells 3 types of behavior profile logs were ran several times within more than two years.
The reservoir under study it is the sand T2 located at Chichimene field, at the Colombia Llanos Basin. It has 320’/250’r of gross/net thickness, physically looks like a singled bed, it is saturated with high viscosity extra heavy oil of 350 cps, it is located at 9000’ measured depth (6000 - 6800’ TVDSS) the permeability shows a broad permeability range of 5 – 10000 mD. Waterflooding was initiated by 2014, the single zone completions wells, were exposed to a 6000 bls/d rate over very high permeability layer and this produced immediate channelization in thin layers only in some weeks after initiated. Producer wells increased water cut to high values, injection rates were controlled as results of its and finally some of the injectors had to be shut in. In the other set of wells, selective applications got separate the sand by 3 or 4 zones, the reservoir sand were irrigated by the same time, at the same rate of 6000 bls/d, almost 2000 bls/d each zone, this time the trends were simply different, means, producers water cut it was low and more stable. The results shows up about 2-3% of RF by simple zone completion in opposite to 6-10% of RF with selectives completions, evidencing a better vertical irrigation.
The case study presented in this paper, it is a successful curiously application of multiple selectives completions within a single sand. This example has been tested in field, it is an effective option in order to increase recovery factor and it will reborn expectations about the use of selectives completions over thick heavy oil sands. This results definitely; it will encourage engineers to think more about mechanical conformance applications in waterflooding.
Improvement of Microemulsion Generation and Stability Using New Generation Chemicals and Nano Materials During Waterflooding as a Cost-Efficient Heavy-Oil Recovery Method
Authors: Lee Jungin , Babadagli Tayfun 
Published: June 2018

Abstract
This study focuses on the ability of complex colloidal solution to stabilize a heavy oil-brine Pickering emulsion by changing the activity at the interface between heavy oil and brine. After testing many different combinations of anionic and cationic surfactants and nano-particles, we formulated the best stability options and created oil-in-water Pickering emulsions stabilized by silica, a cationic surfactant [dodecyltrimethylammonium bromide (DTAB)], and an anionic surfactant [alcohol propoxy sulfate (Alfoterra S23-7S-90)]. Then, various core flooding experiments were conducted in order to demonstrate the practical ability of the created emulsion system and observe its capacity to enhance oil recovery. Rate-dependency flooding tests were also conducted to determine the optimal flow rate required for heavy oil production through emulsification for different permeability media. Ultimately, slim tube sandpack flooding experiment at the optimal rate was conducted to confirm in-situ emulsion generation and to support the potential use of the chemical combination in the heavy oil industry.
Effect of Steam State on the Productivity of a Horizontal Well Pair During the Steam-Assisted-Gravity-Drainage Process: Physical Aspect Analysis
Authors: Zhao Lin , Jiang Hanqiao , Sun Fengrui , Li Junjian 
Published: June 2018

Abstract
Very limited studies were done on the superheated steam-assisted-gravity-drainage (SAGD) process. Besides, study of the effect of physical heating of steam at different state on the productivity during the SAGD process has not been reported.
In this paper, a numerical model is proposed to reveal the effect of physical heating on the productivity of a horizontal well pair during the SAGD process. Results show that: (a) the temperature increase of superheated steam plays a weak influence on the productivity of a horizontal well pair during the SAGD process. (b) the heated area increases with the steam quality, while the increase of the heated area under superheated steam injection is not obvious compared with the heated area when the steam quality is equal to 1.0. (c) as the mobility of oil in the steam chamber increases, the fraction of oil produced from the steam chamber increases, and the pressure near the production well increases. (d) when the steam quality increases or becomes superheated steam, the mobility of the oil in the steam chamber increases, and the supply rate of oil near the production well gradually become larger than the decrease rate of oil in the same region induced by elastic energy. This study provides a
The paper offers a comprehensive insight into the SAGD process, and helps petroleum engineers for SAGD project design in heavy oil reserves.
Applying Project Management Techniques to a Record-Breaking Ultra-Deepwater Frontier Drilling Operation
Authors: Nunes Carlos Eduardo , Smith Vance , Amer Ahmed , Tourinho Diogo Wink 
Published: June 2018

Abstract
This paper highlights the use of integrated project management techniques, as well as innovative drilling fluids technology, to safely achieve drilling objectives on a frontier exploratory, ultra-deepwater project offshore Uruguay. Drilling in a frontier offshore area adds layers of complexity due to inherent uncertainties and risks associated with these types of operations. The use of project management techniques, combined with application of novel drilling fluids technologies, served to mitigate and reduce project risks. Preparation for this well included regulatory review and HSE compliance procedures, facilities and logistics planning, the operator's understanding of the well complexities, selection of experts for each aspect of the operation, and contingency planning to include displacement and emergency disconnect. A thorough and comprehensive readiness review, coupled with communications processes, reinforced the project management loop. Critical path management and efficiencies of drilling operations dictated managing the logistics of mixing large volumes of drilling fluid at multiple locations. The well design program considered the possibility of encountering extreme sediment compaction arising from mass transport complexes (MTC) in the riserless interval. MTCs are a recognized geologic phenomenon and are typically avoided when drilling in deepwater areas of the world.1 The novelty of the workflow involved in safely and effectively delivering this record, frontier ultra-deepwater well included thorough planning and execution, in parallel with the use of new drilling fluid technology and facilities.
Integrated IOR/EOR Screening of an Offshore Oilfield in Trinidad
Authors: Garcia-James Celia 
Published: June 2018

Abstract

Objectives/Scope
An integrated benchmarking and screening study of IOR/EOR technologies used in analogous reservoirs worldwide was performed in the Southwest Soldado (SWS) Field offshore Trinidad, in order to establish the top three methods which could be implemented in this field to increase the recovery factor after more than 30 years producing under primary conditions.

Methods, Procedures, Process
The evaluation of IOR/EOR processes for the Southwest Soldado Field was done in 2 stages. Stage 1 included screening of processes to identify the top 3 methods to be used. Stage 2 involved the detailed evaluation of the top 3 processes. For Stage 1, the National Petroleum Council EOR Screening Method was used along with innovative techniques recommended by industry literature (Taber et al., 1997, Pérez-Pérez et al., 2001). In Stage 2, standard statistical methods were applied to the compiled database of successful IOR/EOR projects in offshore sandstone reservoirs. That information was used to establish a predicted recovery factor for the top 3 IOR/EOR methods selected. A theoretical description of the selected methods and their relationship with Southwest Soldado characteristics was done. Finally, considerations for pilot projects with recommended facilities, required logistics and cost estimates were analyzed and the best options were recommended.

Results, Observations, Conclusions
Given the characteristics of the Southwest Soldado field, Water Alternate Gas (WAG) injection resulted with the highest score based on the benchmarking exercise; Carbon dioxide (CO2) injection and water injection were selected in second and third place respectively. In the case of CO2, it was recommended as Huff and Puff in order to delineate transition zones, for ease of application in existing wells and facilities and for comparatively low cost. This method also generates high oil recoveries in a relative short period of time. Finally, it was recommended that for the implementation of a pilot project, Huff and Puff CO2 injection should be tested prior to WAG injection due to the many advantages in evaluating the reservoirs, quick execution and rapid production results at the lowest investment cost from the other 2 methods evaluated.

Novel/Additive Information
This paper presents the steps taken to benchmark an offshore field in Trinidad using the field's actual data. It lays the foundation for further development of heavy oil reserves in Southwest Soldado, highlights the challenges based on infrastructure, technology and economics requirements and provides a roadmap to further increase the recovery factor of these offshore heavy oil reservoirs.
Strengthening Capability for Oiled Wildlife Management in Trinidad and Tobago
Authors: Hosein Marianne Shalima 
Published: June 2018

Abstract
Despite Trinidad and Tobago having the highest biodiversity in the Caribbean and being an oil and gas producer for over 100 years, there is no approved systematic process to adequately address the protection, treatment and remediation of wildlife in the event of oil spills, apart from what is given in Section 5 of the 2013 National Oil Spill Contingency Plan (NOSCP).
BP Group requirements in 2012 stipulated the need for a documented process to manage oiled wildlife. Using international guidelines, a detailed review was conducted in 2013 to determine what was needed to establish an oiled wildlife preparedness and response programme in BP Trinidad and Tobago LLC (BPTT). This involved engagement of various external stakeholders (regulators, researchers, veterinary services, environmental non-governmental organizations [ENGOs], and international wildlife response organizations) to determine what had been put in place and what could have been established to manage national disasters involving wildlife.
Local animal rehabilitation centres were found to have limited capability to respond to large incidents. BPTT sponsored an Oiled Wildlife Preparedness Response Train the Trainer programme in 2013 to increase the number of volunteers available for oiled wildlife management by enabling the ENGOs to share the techniques with others. Formal volunteer training via ENGOs began in 2017. BPTT also established its own Level 1 Oiled Wildlife Response Kit comprising tools and equipment required to handle, treat and remediate wildlife impacted by oil. While developing its Oiled Wildlife Management Plan, BPTT was asked by the Ministry of Energy and Energy Industries (MEEI) to lead the initiative to further develop Section 5 of the NOSCP in collaboration with the stakeholders mentioned above and the other oil and gas operators. In 2016, the draft national Oiled Wildlife Management Plan was segment-tested during a BPTT major drill that involved a simulated uncontrolled offshore release of hydrocarbon which impacted emerging Green Turtle hatchlings on Manzanilla Beach. The learnings from this drill are being incorporated in the Trinidad and Tobago draft Oiled Wildlife Management Plan which will be added to the next update of the NOSCP.
BPTT remains committed to working with the stakeholders to obtain approval to formally implement this system. In the meanwhile, engagement with the different groups, ENGO training of additional volunteers, drills, data collection from actual incidents continues as capability in oiled wildlife management in Trinidad and Tobago is strengthened.
Risk Management of Major Oil Spill
Authors: Suárez Adriana , Ilizástigui Fidel 
Published: June 2018

Abstract
Major oil spills have the potential to become major environmental incidents. This paper aims to summarize the results of the study aimed at providing oil companies with more effective tools to help them better manage their environmental risks associated with the occurrence of major oil spills during offshore drilling operations. The latter is meant to be achieved by following a rigorous and systematic approach to the integrity management of environmental barriers and the performance of safety critical tasks in the same way the industry has long dealt with the management of integrity thereof.
The paper suggests complementing the approach contained in the IPIECA IOGP guidelines on oil spill contingency planning with DNV guidelines on environmental barrier management. This way the known cycle of ‘assurance and verification' will cover those barriers which are in place to mitigate the effects of major oil spills thus ensuring their availability and effectiveness when are called upon. This includes: a) the identification of environmental critical elements and tasks, b) development of performance standards c) identification of assurance and verification activities and d) the reporting of deviations to senior management levels and taking of corrective actions.
The paper introduces the Bowtie risk management methodology as a tool which supports the barrier management approach by linking technical risk analyses with safety management systems (SMS). This is thanks to its inherent strengths not present in other risk assessment methodologies such as event trees and fault trees. Last, but not least, the introduction of Bowtie methodology will facilitate understanding by all levels of the Oil Company of the role of the barriers in mitigating the effects of accident scenarios and their relationship with other barriers during the control of the accident scenario. The latter is realized through the motto that characterizes Bowtie methodology - ‘A picture paints a thousand words'.
Application of Time-Lapse Pressure Transient Analysis to Predict Gas Water Contact Movement and Water Breakthrough Time: Results from a Reservoir off the North Coast of Trinidad
Authors: Cassie Leon , Yaich Elyes , Singh Sidharth , Kaasa Anne , Jamankulov Arman 
Published: June 2018

Abstract
A single well, satellite gas accumulation offshore North Trinidad exhibits a strong water drive mechanism and is in pressure communication with two neighbouring fields through a common aquifer. Monitoring and predicting the movement of the gas water contact (GWC) is critical to reservoir management and resources estimation. This paper is the culmination of a study that was conducted over a five-year period, analyzing high quality downhole pressure buildup data to track the GWC movement in the field. Analysis of late time boundary dominated flow regime in multiple time lapsed pressure derivatives indicated a movement in the gas-water phase boundary, believed to be the contact. Pressure transient analysis (PTA) enabled the translation of shifting pressure derivatives to alternate GWC contour realizations. These matched derivatives provided a quantitative estimation of the contours which were then converted to an equivalent contact radius. For both edge water or bottom water drive mechanisms, the equivalent contact radius was then correlated to the field's cumulative gas produced. Prediction of water breakthrough was done by estimating a range of contours arriving near the well and calculating the corresponding recoverable gas volume from the generated correlation.
Multiple analytically derived functions were used to correlate the equivalent contact radius with the gas produced. A strong correlation was observed on regressing produced volumes with the interpreted contact radii. Due to inherent uncertainties with sweep efficiency, as a proxy, three idealized cases were defined for arrival of water close to the well to capture a low, mid and high scenario. Using these cases, water breakthrough was predicted to occur for produced volumes in the range of 58 Bscf to 70 Bscf, with a mid-case of 64 Bscf. In May 2015, actual water breakthrough occurred after 62 Bscf of production thus, strongly validating the robustness of the time lapse pressure derivative analysis study.
For gas reservoirs supported by moderate to strong aquifer drive, we suggest this as a robust workflow independent of 3D numerical reservoir simulation to predict recoverable volumes and water breakthrough timing. The observation of contact movement for gas reservoirs connected through a common aquifer could have significant implications on the conventional understanding around such reservoirs and their optimum management strategy.
Effect of Temperature, Phase Change, and Chemical Additive on Wettability Alteration During Steam Applications in Sands and Carbonates
Authors: Pratama Randy Agra , Babadagli Tayfun 
Published: June 2018

Abstract
One of the unanswered issues with steam applications is the wettability state during the process. Removal of polar groups from the rock surface with increasing temperature improves water wettability; however, other factors, including phase change, play a reverse role on it. In other words, hot water or steam will show different wettability characteristics, eventually affecting the recovery. On the other hand, wettability can be altered using steam additives. The mechanism of these phenomena is not yet clear. The objective of this work is to quantitatively evaluate the steam-induced wettability alteration in different rock systems and analyze the mechanism of wettability change caused by the change of the phase of water and chemical additives.
Heavy-oil from a field in Alberta (27,780 cP at 25°C) was used in contact angle measurements conducted on mica, calcite plates, and rock pieces obtained from a bitumen containing carbonate reservoir (Grosmont). All measurements were conducted at a temperature range up to 200°C using a high-temperature high-pressure IFT device. To obtain a comprehensive understanding of this process, different factors, including the phase of water, pressure, rock-type, and contact sequence were considered and studied separately.
Initially, the contact angles between oil and water were measured at different pressures to study the effect of pressure on wettability by maintaining water in the liquid phase. Secondly, the contact angle was measured in pure steam by keeping pressure lower than the saturation pressure. The influence of contacting sequence was investigated by reversing the sequence of generating steam and introducing oil during measurement. These measurements were repeated on different substrates. Different temperature resistant chemicals (surfactants and alkalis) were added to steam during contact angle to test their wettability alteration characteristics at different temperature and pressure conditions (steam or hot-water phases). The results showed that wettability of tested substrates is not sensitive to pressure as long as the phase has not been changed. The system, however, was observed to be more oil-wet in steam than in water at the same temperature, for example, in the case of calcite.
Analysis of the degree of the wettability alteration induced by steam (or hot-water) and temperature was helpful to further understand the interfacial properties of steam/bitumen/rock system and useful in the recovery performance estimation of steam injection process in carbonate and sand reservoirs.