bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Hybrid Enhanced Oil Recovery Method by Smart Water-Injection and Foam-Flooding in Carbonate Reservoirs
Authors: Hassan Anas. M. , Ayoub Mohammed , Eissa Mysara , Bruining Hans , Al-Mansour Abdullah , Al-Guraishi Abdulrahman 
Published: October 2019

Abstract
This contribution focuses on recovery of oil by using a newly hybrid Enhanced Oil Recovery (EOR) method, which combines smart water (i.e. ionically modified brine) and foam flooding of light oil with dissolved carbon dioxide at high pressure in carbonate reservoirs. Ionically modified brine (i.e. low salinity) has a dual improvement effect. It not only leads to more stable foam lamellae, but also helps to change the carbonate rock wettability from oil-wet to more water-wet, which has for some conditions more favorable relative permeability behavior. The mechanism for the modified permeability behavior in the presence of ionically modified brine is only partly understood. Therefore, we use the DLVO (i.e. Derjaguin, Landau, Verwey, and Overbeek) theory (i.e. which considers double layer repulsion, born repulsion, and Van der Waals attraction) and surface complexation modeling to better understand the mechanism(s) of ionically modified brine as wettability modifier and foam stabilizer. We use the PHREEQC software to obtain the equilibrium concentrations and surface potential and to study the effect of salinity and carbon dioxide gas pressure for a given choice of the surfactant (i.e. carboxylic acid R-COOH). It is conjectured that high carbon dioxide pressures have a destabilizing effect on the film, as they reduce the surface potential. A reduced surface potential leads to a decreasing electrostatic double layer repulsion and thus destabilizes the stability of the foam film, whereas low salinity leads to less screening of the surface potential and thus improves the stability of the foam film. The low-salinity flow is characterized by a high residual oil saturation and low end-point permeability for the two-phase oil-water flow. For the calcite surface an enhanced stability help to stabilize the water film on the calcite surface if the oil-water surface charge has the same sign as the surface charge on the calcite surface. Our calculations show the pH range where the sign of these charges is the same or opposite at low-salinity and high-salinity conditions. Admittedly, these calculations only show trends, but can be used to delineate optimal conditions for the use of combined Smart Water Assisted Foam (SWAF) flooding.
Analysis of Friction Reduction System during Drilling Operation at High Inclination Well on Field X
Authors: Mudhoffar Rizqiana , Lumbantobing Jerry M. , Bayuartha Pratama 
Published: October 2019

Abstract
Torsional vibrations (stick slip) and limited reached drilling are slowing down drilling operations and increasing drilling costs. Therefore, to mitigate these problems, the use of Friction Reduction System (FRS) is considered. FRS is a system commonly used to reduce downhole friction during drilling operations. Drilling parameter results are compared with offset well that had high stick slip.
The approach was based on qualitative research method, data processing obtained from the drilling operation of the well X. The method was performed by evaluating the use of FRS in the BHA series during the drilling operation. Such method mainly revolves around calculating some drilling parameters such as Torque, Weight on Bit (WOB), Rate of Penetration (ROP), Revolutions per Minute (RPM) and analysing the log results of the tools contained in the Rotary Steerable System (RSS) and Measurement While Drilling (MWD), as well as comparing it with offset well Y, which had high stick slip.
The result of data analysis shows that the use of FRS tool on drilling of well X is more effective and efficient compared to well Y, evidenced by drilling parameter such as WOB and Torque that are reduced by around 30%, with downhole and surface RPM being relatively constant, and supported by log results that do not show any signs of stick slip. Furthermore, the use of FRS tool is compatible with BHA component (Mud Motor / RSS / MWD / LWD) as no problems was caused by FRS on the dynamic data of drilling well X. By comparing the two wells, the use of FRS on well X proved the ability to reduce the stick slip and increase weight transfer, thus reducing the cost of drilling.
The expected result of this analysis is a reference to the use of FRS tools as a component of BHA that is placed a few feet away from the bits in accordance with its effectiveness level that can reduce the potential hazards of stick slip vibrations and expected to improve drilling efficiency in terms of time and cost.
Systematic Management for Drilling Process Improvement
Authors: Damski Carlos 
Published: October 2019

Abstract
Today every Oil & Gas company is talking about Digital Transformation as a new mantra, making reference to the more recent digital technologies such as IoT, Big Data, Machine learning, etc. Historically we already have seen such "transformations" in the past, such as agricultural revolution with tractors and such, the industrial "revolution" with assembly line and mass production, etc. There is nothing intrinsically new about the recent "digital revolution" and it is more like a déjà vu situation, raising similar questions and some dreadful future scenarios.
Using the basic tripod of people-process-technology, I would argue that the people are the same, regardless of the "revolution". The "technology" is just the enabler of the revolution, the same as the tractor or IoT technology. What really matters is the "process" of how people can use the technology to deliver improved results. Hence, this paper looks into the drilling business from a "process management" perspective as a means to effectively use the digital technology currently available.
Over the last 100 years, "scientific management" has been used or was used as a basis for many current process management styles. Understanding what has worked and what has failed in the past. Learning from the past, gives us a better model for the process to use the current flood of data measurements.
I would like to propose some working models for drilling continuous process improvement, a methodology and some guidelines used.
The EOR Mechanism and Flow Behaviors of High-Viscosity Modified Starch Nanogel Particles in Porous Media
Authors: Liang Tuo , Hou Jirui , Qu Ming , Wen Yuchen , Zhang Wei , Wu Wenming , Wu Weipeng , Zhang Ziyi , Yang Jingbin , Xiao Lixiao , Ding Yitong 
Published: October 2019

Abstract
The formation of the dominant channel of water is a severe problem for most of the oilfields. Recently, gel and nanoparticles regarded as conformance water materials have attracted more attention to control water-cut and enhance oil recovery (EOR) in many water invasion reservoirs. However, nanogel particles possessing synergic properties of nanoparticles and gel are currently unavailable, which causes barrier to EOR. Here, high viscosity α-starch nanogel particles were synthesized to play the synergistic role of gel and nanoparticles economically. The average diameter of nanogel particles was 30 nm with dispersion viscosity of 250 mPa·s at 90°. Through flooding experiments, we demonstrated both light and heavy oil recovery rates reached around 30%. The nanogel particles promotes to displace oil droplets from the rock surface due the creation of the structural disjoining pressure. Also, its high viscosity properties help to drag oil clusters out of the oil phase.
A New Method to Evaluate Potential Hydrocarbon in Hard Overpressure Zone
Authors: Apranda Yoseph Robby , Riadi Ridha Santika , Nugraha Teguh , Permana Robhy Cahya , Putranto Asnanto Multa , Noerad Dardji 
Published: October 2019

Abstract
The Sanga-Sanga working area consists of brown fields that have been produced for nearly 50 years. The production is declining rapidly from anticlinal trap fields. Finding new resources is a must in order to extend the production life. Therefore, the exploration requires getting deeper targeting reservoirs associated with hard overpressure zones.
The methodology used to identify and recognize the potency of hard overpressure zone is the integration of geology, geophysics, and geochemistry data. Normal compaction trend and pore pressure analyses were performed to determine top of overpressure zones. The geochemical data from biomarker provide calculated vitrinite reflectance (Rc) to complement vitrinite reflectance (Ro) when evaluating relationship between hydrocarbon origin and overpressure generation. Finally, the seismic integrates all the data in structural reconstruction framework.
Pore pressure analysis showed 9 wells have overpressure zones. The overpressure occurrence can be grouped based on anticlinal lineaments. The Badak-Nilam lineament is characterized by a sharp change in overpressure to hard overpressure zone, distal facies, relatively normal deposition and showing higher pressure gradient. The Semberah and Lampake-Mutiara lineament are characterized by long transition zone, proximal facies, strongly uplifted and folded, and showing lower pressure gradient. Ro and Rc data showed that there are two periods of hydrocarbon charging into the reservoir, prior to and after the hard overpressure zone occurred. Vertical effective stress, dynamic mechanism, and the timing hydrocarbon generation-migration and overpressure generation hole significant role to accumulation.
The evaluation of hard overpressure zone play requires the integration of geology, geophysics and geochemistry to get the understanding of the timing sequence between hydrocarbon generation-migration and overpressure generation. Calculated vitrinite reflectance data from biomarker gave an advantage to this timing relationship that could lead to the exploration of the hidden resources in the hard overpressure zone becomes more feasible.
New Perspective to Unlock Opportunities in Mature Field: Sanga-Sanga Block, Indonesia
Authors: Fedriando Fedriando , Pambudi Aldy Reza , Rolanda Donna Sita , Srikandi Citra , Nugroho Agung Prasetyo , Fadhlirrahman Ahmad Arif , AD Addil , Satria Tedi 
Published: October 2019

Abstract
Sanga-Sanga Block is located onshore of the Mahakam delta, in East Kalimantan Indonesia and operated under Pertamina Hulu Sanga-Sanga. Nilam field, one of assets in Sanga-Sanga Block was discovered in 1974 with 75 km length. Nilam field was interpreted as the extension of Badak Handil Anticline Structure. The first well, NLM 1 was spudded on 8 July 1974 and put on production 9 years later due to waiting on surface facility. Early production was 22 MMscfd and flow directly to Bontang. At present, Nilam has reached a mature stage of its life where 364 wells drilled. The productions are continuing declining and currently 98 wells online and deliver approximately 23 MMscfd and 1800 BOPD.
There are 3 components to generate the production; they are base, rigless and new well program. New well program is main contributor to Nilam production. However, since oil price start to drop in 2014, drilling activity becomes decreased and consequently, rigless activity become the main backbone to arrest production decline. Aggressive rigless program is required to maintain Nilam production. Since 2010, total of perforated zones are 1323 and by the time, thus remaining zone candidates for rigless are decreasing. To face this challenge, integrated subsurface review has been conducted to assess several strategies to create new opportunity in delivering Nilam production. The strategies are; unlocking the hidden potential from by passed and unprognosed zones in existing well and campaign of complex rigless program to access the potential zones.
In early 2018, these strategies has already applied and already contributed 4.42 Bcf and 164 thousands of barrel oil to Nilam Field. The success ratio is 73%. It helped to sustain Nilam production and maintain the decline rate. In summary, these strategies have successfully unlocking hydrocarbon potential and maximizing recoverable reserve in existing wells which resulted in extend the field life. This paper will describe the success story to unlock gas and oil reserve in complex environment especially at Nilam Field.
Sour Gas Facilities Debottlenecking: Establishing Feasible Operational Boundaries for Higher Contaminants Processing
Authors: Muhamad Ir. Suhana , Ahmad Johari Ir. Ahmad , Abdullah Nur Hidayah 
Published: October 2019

Abstract
Gas fields containing contaminants continue to not only challenge new field development projects, but also existing operations worldwide. Unforeseen variables such as increasing levels of contaminants from existing fields paired with increased sales gas demands, justifies the urgent need of identifying limits and pushing boundaries of existing facilities to handle the operation parameter changes.
This study focuses on a debottlenecking study done for an existing operational facilities located at the Caspian Sea area, with an original inlet H2S design of 45 ppmv, to be processed down to &lt; 3.5 ppmv. New sales gas demand requires for the existing facilities to process sour gas from reservoir having a maximum level of 580 ppmv H2S, at a higher continuous sales gas volume. Challenges to achieving this also includes uncertainties due to fluctuations of H2S levels from the reservoirs, with some variations going from &lt;10 ppmv to 300 ppmv H2S coming out from the same well.
Discussion will elaborate on challenges in meeting the new sales volume with expected increased in H2S levels from existing wells, and how limitations of existing facilities (Acid Gas Removal Unit, Acid Gas Incinerators and materials sour service compatibility) are addressed to produce a feasible operating envelope, with minimal changes to existing operating facilities.
Actual operating data from approximately 5 years of operation was analyzed to determine the feasibility of the AGRU and Incinerator to handle higher H2S levels in feed. This is in anticipation of continuous feed gas volume of 500 MMscfd, at blended H2S levels of between 45 ppm to 162 ppm (worst case scenario). Existing facilities sour materials compatibility analysis are also done to determine the feasibility of the operating envelope.
In the analysis, data from actual operating history and new production profiles are plotted against a feasible operating curve developed for the AGRU. The resultant graph gives an indication of the existing AGRU capability to manage incoming increase in gas volume and H2S levels. The analysis also evaluates the impact to the Incinerators, with new emission dispersion simulations done, to ensure operating curve complies with local environmental regulations on emission dispersion.
The analyses conclude that the existing facilities is deemed adequate to handle new gas demand, with some curtailment on blended H2S levels to ensure only minimum changes and upgrades are required to existing facilities. The curves developed are hereby used as a reference for operations of the facilities in the future, whilst the methods applied here can be used as a reference for future sour facilities debottlenecking.
Numerical Simulation of Improving Cementing Displacement Efficiency under Narrow Safety Density Window
Authors: Gao Haiyang , Ai Zhengqing , Zhang Jingcheng , Zhou Bo , Chen Feng , Wang Wenchang , Liu Zhongfei , Deng Qiang , Shi Yongzhe , Wang Zhongli 
Published: October 2019

Abstract
As for the thick salt-gypsum formation and the target strata in the Kuqa piedmont zone of Tarim basin in western China, The biggest challenge in well cementing is the narrow safety density window (only 0 g/cm3-0.1 g/cm3 or 0ppg-0.833ppg) and the unsatisfactory leakage blocking technology under pressure (the improvement of formation pressure-bearing capacity is less than 0.1 g/cm3 or 0.833ppg). The limited flow rates (0.6m/s-1m/s lost still) during cementing operation are distinctly insufficient for displacement efficiency. In response to this challenge, a numerical simulation study has been carried out using the computational fluid dynamics (CFD) software ANSYA Fluent to explore practical guidelines in these formations.
The models we build are annulus with a 176.7mm (6 5/8 " bit expanding 5%) outer diameter for the hole and a 139.7mm(5 1/2") inner diameter for the casing, the length is 11 meters or 22 meters, and the eccentricities are 0.3, which means a sufficient centralizer according to our practical experience. The 11-meter and 22-meter models have one million and two million grids, respectively. In the thin boundary layer area four thin boundary layers were constructed. The species model and the viscous laminar model have been applied, and the velocity inlet and the outflow outlet have been set as the boundary conditions. Both the mud, the spacer and the cement slurry are non-Newtonian Herschel-Buckley(H-B) fluids, whose rheological properties are determined by the flow index n, consistency coefficient K and yield point YP. By analyzing the interface characteristics of the mixing slurry, distribution of mud mass fraction and wall shear stress at different inlet velocity and displacing time during the displacement process, the effects on the displacement efficiency for each individual factor, such as casing centralizer, flow rate, and rheological properties, have been analyzed and summarized.
According to these simulations, a series of guidelines have been drawn. A sufficient casing centralization is the most important approach to improve the displacement efficiency. Flow rate and wall shear stress also play an important role, but they are limited by the safety density windows of the formations. Under the circumstances, the most practical way to improve the displacement efficiency is to optimize the rheological parameters of the mud-spacer-cement slurry (for instance, to decrease the consistency coefficient K and yield point YP of the spacer) to achieve a larger friction gradient difference and get a better displacement efficiency eventually.
These guidelines, which have been applied in the X-well of Kuqa piedmont, have shown a remarkable achievement in cement sheath evaluation across the primary zone of interest (qualification rate improved from an average 49% to 80.3%), and therefore are practical in the formations with narrow safety density window.
Towards a Reliable Determination of Saturation Pressure: A Hybrid of Mouth Brooding Fish MBF Algorithm and Flash Calculations
Authors: Ebadi Mohammad , Koroteev Dmitry 
Published: October 2019

Abstract
Determination of the saturation pressure as one of the most prominent PVT properties of each oil sample has been the topic of many expensive and time-consuming experimental and numerical methods. The current research aims conducting a systematic search procedure to estimate the saturation pressure of an oil sample based on the application of flash calculations tuned with a modern optimization algorithm.
The saturation pressure is the only one at which the total product value of Zi (mole fraction of component i in the entire hydrocarbon mixture) by Ki (pressure dependent equilibrium ratio of component i) is equal to the unity. Instead of using a trial-and-error method to compute a pressure which satisfies the abovementioned condition, advantages of metaheuristic algorithms like Mouth Brooding Fish (MBF) can be utilized to evolutionarily find the saturation pressure.
The pressure of each cichild has been evaluated based on a cost function which relies on values generated with Equations of States (EOS). The squared difference between the generated output and the unity is the amount of error which has been minimized within the running of the MBF.
Whereas the determination of saturation pressure through the application of flash calculations has traditionally been a challenging case in terms of providing a proper initial guess, the proposed procedure has turned the previous method into a systematic, super-fast and programmable trend which can easily be inserted into the commercial packages of reservoir simulations.
Integrated Hydrocarbon Asset Management: Efficient Strategies and Innovative Solutions
Authors: Masoudi Rahim , Jamaludin Maisarah 
Published: October 2019

Abstract
The 2015 oil price downturn compounded by future uncertainties and volatility in the industry have resulted in significant transformation in many oil & gas companies towards identifying and removing inefficiencies and maximising the lifecycle value of the hydrocarbon assets. The need to take proactive action in enhancing the business workflows to improve efficiencies through process simplification, innovative collaboration models and cost reduction efforts. In the low oil price environment, we need to be more cash conscious, focusing mindset towards value & objective driven activities, while rethinking the commercial and contractual strategies.
This paper will briefly touch upon some of the process improvements at industry level in Malaysia and its key principles and value impacts, focusing mainly on Integrated Asset Development & Management (IADM) throughout field/asset lifecycle from exploration stage to decommissioning and abandonment stage. In addition, this paper will also share examples of innovative solution of resources management towards successful development plan formulation and asset management, that serve as a platform for putting together various elements of ideas and concepts, best practices and lessons learnt, techno-commercial & data-driven initiatives, alternative industry standard approaches, and enabling technologies for IADM.
Optimizing Operating Cost Through Production Management and Techno-Economic Approach in Mature Field and Gross-Split Scheme
Authors: Nugroho Wisnu Agus , Panaiputra Harris Grenaldi , Kusuma Dian Nurlita , Wirawan Alvin , Hartawan Iman Budi , Hapsari Ratna 
Published: October 2019

Abstract
Currently Indonesia apply new gross split production sharing contracts for the oil & gas industry. Regulation of the Minister of Energy and Mineral Resources Number 8 of 2017 on Gross Split Production Sharing Contracts sets out a new economic structure for production sharing contracts (PSC) based on dividing gross production between the state and PSC Contractors, without a mechanism for the PSC Contractor to recover operating costs. For mature field, high operating cost regarding low production, high maintenance, and integrity issues are challenging for this new regulation. To optimize operating cost with robust and prudent planning is one of the key of success in this era. Pertamina Hulu Energi Offshore North West Java (PHE ONWJ) has started gross split scheme since January 2017 which start a new era of production sharing contracts.
With the start of gross split scheme, prioritization of production is the main objective, to gain maximum productivity in terms of operating and lifting cost. The methodology to optimize operating cost is by prioritizing productive remote well platform, Normally Unmanned Installation (NUI), by ranking of potential development and its production volume. The non-potential and non-productive NUI then be assessed to be shut off or run to fail. The assessment conducted using technical and economic approach to obtain optimized result. For non-potential and productive NUI, assessment to gain more production with minimum cost is conducted. Then, development could be focused on potential and productive NUI.
Foxtrot, one of flow station in PHE ONWJ working area, has eight active NUIs that are FA, FK, FG, FFB, FNB, FWB, HZEA, and HZEB. By conducting ranking of potential development and its production volume, company could focus on five Foxtrot NUIs for development (FK, FG, FFB, FWB & HZEA), two NUIs for optimization (FNB & FA), and one NUI that potential to be shut-off, HZEB. This action on the non-potential and non-productive NUI shut off could yet decrease operating cost by IDR 8.8 Billion/ year, eliminate potential personal hazard, and reduce system's backpressure due to its low API crude oil. Oil and Gas Company that operates old facilities in mature field could apply this approach to maintain their production by focusing on beneficial asset yet decrease operating cost.