bluuebunny/crossref_metadata_2025_split huggingface dataset:
Smart Field: Is it Really Smart-Donkey Field Experience
Authors: Ariffin Mohd Hafizi , Tham Su Li , Johing Fedawin , Jamel Delwistiel , Abdussalam Khomeini 
Published: October 2019

Abstract
Smart field accessories are already widely used in the industry. Donkey field is ready to jump on the bandwagon by installing 8 wells with these accessories. In addition, Donkey field is equipped with data transmission system or we called it Integrated Operation (IO) where the data is transmitted directly to shore for faster decision making and continuous data monitoring.
For every installation for these jewelries, the question is always why do we need these? Most of the time, well inaccessible is the drive of their installation. But, the benefit of this jewelries are beyond that. For example, optimization for commingle is easier for this installation. With Inflow Control Valve (ICV), it is easier to control its injection for each layer.
IO helped the engineer to dive deep into well and reservoir performance or problem. This technology helps the engineer to have full picture on field potential. So, where is the problem?
"Smart well" have a good ring to our ear which make us forget what is the challenges underlying its installation. After 2 years of its installation, almost all these jewelries began to shows their problem. Team face quite a challenge to rectify this problem especially on well jewelries. Because of the location of the field, transmitters’ signals are really impacted by the weather. With the tropical climate of Donkey field, the data missing for interpretation is quite massive. Hence, it is difficult to get good data for it.
During initial design stage, everyone need to consider the configuration and location of the field before we start to consider these expensive jewelries. Do we really need it? And are we ready for its maintenance, not just on its installation? How frequent is its maintenance? All of these need to be considered before we jump on the bandwagon.
Lessons Learned from Adopting Sustainability Aspects for Gas Development Project
Authors: Asmoro Trian Hendro , Prabowo Hirmawan Eko , Prayascitra Adearty 
Published: October 2019

Abstract
Oil and gas industry have started integrating sustainability approaches into their oil and operations mainly aiming to manage risks particularly in Environment and Social (E&S) aspects. It is also seen to be aligned with Sustainable Development Goals (SDGs) where its main principles of sustainability have actually been adopted in the oil and gas activities. One of set of requirements that addresses sustainability aspects in a project is that Performance Standards (PS) developed by IFC (International Finance Corporation).
IFC PS provides comprehensive standard of E&S practices which encourages transparency and positive contribution to environment and community. It has 8 elements, i.e. managing E&S risks and impacts (PS1), promoting safety and fair treatment of workers (PS2), avoiding pollution from project activities (PS3), managing risks to local communities (PS4), improving livelihoods of displaced persons (PS5), managing living natural resources sustainably (PS6), and protecting the indigenous peoples (PS7) and cultural heritage (PS8).
Adopting IFC PS has been mostly becoming compulsory nowadays when dealing with financial institutions to support a project financing. This is also known as green financing where a project must adhere with a set of E&S requirements in managing project risks especially in E&S sides. Implementing IFC PS is such a challenging thing when the project has unique characteristics, e.g. located in post-conflict area, no major project in the past decade, and some unpleasant images perceived by the communities from the former operator.
This paper will discuss lessons learned from implementing IFC PS in a gas development project and developing management system adopted from them, e.g. stakeholder engagement, grievance mechanism, livelihood restoration and environment management. It will also investigate the gaps between aspects in IFC PS and Government regulation, and finally bridge them accordingly. As a result, implementation of management system has helped manage the risks and improve project's performance and outcomes.
Dynamic Well Modeling, Where are We?: Mahakam Operation Experience for Well Diagnostics & Optimization
Authors: Ashfahani Adnan Syarafi , Sulistiyo Sulistiyo , Hapsari Hairuni Safri 
Published: October 2019

Abstract
Since first time introduced in oil & gas well by Gilbert (1954) then popularized by Mach (1979) and Brown (1984) as Nodal Analysis™, system analysis is commonly used to analyze the performance of system composed of multiple interacting components. It is generally used for well diagnostic, performance matching, and prediction for optimization. In this concept, multiphase flow modeling in steady-state condition also introduced and widely used in industry to analyze flow performance inside wellbore with empirical or mechanistic approach. However by its nature, flow performance always as transient flow phenomenon and several cases could not be captured by steady-state model. Dynamic well modeling is needed to verify some of the conclusions from steady-state simulation therefore uncertainty could be reduced. Dynamic model features mechanistic & empirical approach with basic conservation equations (mass, energy, momentum), constitutive correlations and flow pattern transition modeling (Benidiksen et al, 1991; Staff et al., 2015). It is a powerful approach to generate model where dynamic-transient phenomena is become concern.
Dynamic well modeling has been demonstrated in latest 5 years of Mahakam operation for specific purpose where steady-state well model which regularly used could not represent dynamic condition. Several studies are presented in this paper with certain objectives for well diagnostic, optimization, risk analysis or in general for petroleum engineering purpose: 1) Liquid loading prediction; 2) Well start-up prediction & analysis; 3) Static condition requirement analysis for well revival campaign; 3) Velocity String performance prediction; 4) Alternative water production estimation where direct measurement has limitations; 5) Wellhead shut-in pressure prediction with buffer zone effect to support unlocking high pressure reservoirs; 6) Blow-out modeling and dynamic well killing for blow-out contingency plan; 7) Unstable gas lift injection phenomena that impact to liquid production; 8) Liquid accumulation inside pipeline which impact to well back pressure, etc. The advantage and drawbacks from model implementation also presented as a practical reference to consider this approach. In summary, dynamic well modeling is beneficial in Mahakam operation, moreover in today's mature condition (operated more than 40 years) where the problem becomes more complex and better decision making is needed to consider efficient method with effective cost.
Unlocking Potential of Handil Shallow Oil Reservoir by Using Resin Sand Consolidation Technique
Authors: Hadi Aen Nuril , Setiadi Rahman , Agus Yasa I-Made , Setyo Handoko Bayu , Nursyirwan Ahmad 
Published: October 2019

Abstract
Handil Field is a mature oil and gas field located in Mahakam Delta, East Kalimantan, Indonesia, developed since 1975. Handil reservoirs were deposited in a fluvio-deltaic environment. Oil reservoirs mainly located in shallow zone, whereas gas bearing reservoirs are mainly located in lower main until deep zone. Handil shallow zone consists of multi layer reservoirs located at depth 200 to 1500 m TVDSS. This zone is penetrated by different kinds of completion well techniques: gravel pack well for shallow zone and tubingless and dual string well for main and deep zone. The oil production from shallow zone is supported by gas lift system. The characteristic of shallow reservoir is poorly consolidated to unconsolidated sand with strong aquifer support. Due to sand prone reservoir, sand control technique is mandatory to prevent sand production when producing the oil.
Gravel pack is commonly used as completion technique. Yet it still has limitation in number of reservoir coverage. As an alternative solution to produce remaining uncovered oil reservoirs, resin sand consolidation (SCON) is chosen.
As the impact of bottom-up perforation strategy applied in Handil field, SCON implementation in ex-main and ex-deep zone wells are continuously emerging. Currently, several wells start producing from shallow reservoirs. Extensive preparation should be performed such as gas lift installation, tubing integrity, cementing, and site preparation in order to perform SCON in these types of wells. In terms of SCON target selection, several assesment should be performed to deal with SCON chemical limitations.
SCON technique in Handil shallow oil reservoir was put on pilot project in 2011. Until End of 2018, 19 jobs have been implemented in different type of well architectures. In term of production gain, SCON jobs have been delivering ~1,100,000 bbls cumulative oil production with 100% success ratio on job execution and durability of the resin (no early sand breakthrough on surface). In 2018, 11 SCON jobs were performed with an average production gain 400 bopd and reserves 80,000 bbls. Due to its profitability, robustness, and applicability, SCON remain the main option to unlock oil potential of the remaining unperforated shallow reservoir in Handil Field.
Management of Reserves in Mature Oil and Gas Fields
Authors: Peacock Douglas , Duncan Andrew 
Published: October 2019

Abstract
Many basins throughout the world are experiencing decline in hydrocarbon production with fields maturing and approaching abandonment. Growth in production is coming either from unconventional reservoirs or from relatively immature and emerging basins. As fields (or clusters of fields) approach abandonment, several issues need consideration. There are several ways in which production decline can be mitigated including: infield drilling, workovers, optimised reservoir & facility management, field rejuvenation. Cost management, increased production and operational improvement are some of the strategies employed to maintain profitable operations.
Abandonment of a platform with a large number of wells can be a lengthy process with production continuing throughout that process. As production declines, revenues will eventually no longer cover costs. Within the Petroleum Resources Management System (PRMS), Reserves are limited by "the earliest truncation of either technical, license, or economic limit". If there are no technical or licence restrictions, the economic limit, defined as the the time when the maximum cumulative net cash flow occurs for a project, defines the date up to which Reserves may be booked.
Several issues related to the determination of the economic limit by an Economic Limit Test (ELT) in late field life will be discussed. Short periods of negative cash flow may be accommodated, and therefore qualify as Reserves, under certain circumstances provided that the longer term cumulative net cash flow forecast shows that the following positive periods more than offset the negative. The use of maximum cumulative cash flow as the basis for the ELT means that incremental projects with negative cash flow are not included as Reserves. However, once the costs are sunk and a forward-looking assessment is performed, the cash flow is once again positive and Reserves can be assigned. Volumes being produced beyond the economic limit, accompanied by a negative cash flow, should not be classified as Reserves as they are not economic to produce. The assumption within the PRMS is that this is point at which a project will cease production.
In some PSC environments, there may be little incentive for operators to make long term investments close to PSC expiry. Even after fields reach their economic limit, they may be reactivated e.g.by infill drilling, IOR, EOR. This may be done by different operators, including National Oil Companies or service companies and/or under different commercial arrangements. However, in practice, there may be several reasons why fields continue to produce when production is sub-economic. Management of Reserves in mature fields is important for many reasons including: providing a financing base for the operator, signalling investment opportunities for field re-activation, improved recovery methods or to justify licence extension. This paper will outline some of the challenges involved in late life field management and how it impacts Reserves assessment.
Wettability State and Phase Distributions during Steam Injection with and without Chemical Additives: An Experimental Analysis Using Visual Micro-Models
Authors: Pratama Randy Agra , Babadagli Tayfun 
Published: October 2019

Abstract
Our previous contact angle measurements showed that phase change plays an essential role in wettability, thus impacting heavy-oil recovery. While oil is the strongly wetting phase in the steam zone, it becomes the opposite in the condensation (hot-water) zone—regardless of temperature. We also showed that the reverse wettability can be changed using new generation chemicals including thermally resistant chemicals (special surfactants, alkalis, water soluble solvents, and ionic liquids). Even though they reveal useful information, contact angle measurements are limited in accounting for the importance of the wettability alteration effect on the phase distribution/entrapment and oil recovery. Micromodel studies are then preferred to assess these characteristics.
All observations and measurements in this research were conducted at temperatures up to 200°C on glass bead micromodels. The models were initially saturated with brine solution and then displaced by two types of mineral oils (450 cP and 111,600 cP at 25°C) to maintain initial water and oil saturation. Hot-water was then constantly injected into the micromodels to evaluate the impact of phase change and wettability status on residual saturation development. Similar parameters were also evaluated in pure steam injection by elevating the temperature to match the steam temperature and maintaining pressure below saturation pressure. Next, several chemical additives screened from the previous contact angle and thermal stability measurements were introduced during both hot-water and steam applications to observe their ability in modifying phase distribution, wettability state, and oil recovery at different pressures and temperatures.
The result of the experiments in the glass bead micromodel presented that phase distribution and wettability state were sensitive to steam phase (vapor yielded oil-wet or condensate yielded water-wet case). This phenomenon also aligned with the previous hypotheses indicating that phase change has an impact on the wettability state and residual oil saturation. At any circumstances, wettability alteration with chemicals was possible with the anionic surfactant and SiO2 nanofluid. The shape and characteristics of the trapped oil with and without chemicals were identified through micromodel images and suggestions were made as to the conditions (pressure, temperature, and time to apply during the injection application) at which these chemicals show optimal performance.
Study and analysis of phase distribution and wettability change in micromodels during hot-water and steam applications provide useful data and understanding of interfacial properties, oil trapping mechanism, and recovery performance of rock/bitumen/hot-water or steam system in the reservoirs. For practitioners, chemical additives were recommended, validated by visual images and thermal stability tests.
Improvement of Operational Excellence: Reducing Unplanned Production Deferment
Authors: Lim Jit Sen , Kueh Jing Zhi , Maskawi Bolhi 
Published: October 2019

Abstract
In the upstream oil and gas production sector, unplanned production deferment (UPD) is defined as the conduit production flow deviation from technical potential due to unscheduled interruptions. Low UPD is a key indicator of a facility's operational excellence. High UPD reflects that a facility is facing frequent downtime of critical equipment, poor work schedule planning and execution, under-performing producer wells, inability to meet the facility's production targets, increased expenditure, as well as possible additional work-related stress among the employees. In this case study, UPD of a Malaysian upstream brownfield production facility is mostly affected by wells-related (33%), process-related (31%), and rotating equipment (25%). A clear framework has to be in place to resolve and address the UPD, with improvement recommendations detailed out for deliberation. The outcomes of UPD reduction efforts heavily depend on the integration as well as collaboration of people, processes and technology.
A Modified Embedded Discrete Fracture Model to Improve the Simulation Accuracy During Early-Time Production of Multi-Stage Fractured Horizontal Well
Authors: Rao Xiang , Cheng Linsong , Cao Renyi , Jia Pin , Dong Peng , Du Xulin 
Published: October 2019

Abstract
This paper pointed out that the simulation accuracy of original embedded discrete fracture model (EDFM) during early-time production of multi-stage fractured horizontal well is low due to the linear pressure distribution assumption in matrix cells containing fracture cells. To resolve the above limitation of original EDFM, a modified EDFM is presented by adding multi-layer virtual cells adjacent and parallel to fracture cells and changing the connections between cells. This modified EDFM can make the same function like LGR technique, and does not bring any complexity to pre-processing algorithm of EDFM, especially for its 3D implementations. A test case and an application example for complex fracture network are implemented to verify that this modified EDFM can significantly improve the early-time simulation accuracy to greatly eliminate the errors of the original EDFM.
Highly Efficient Nanocrystalline Cellulose Cross-Linker for Fracturing Fluid System
Authors: Zhang Chuanbao , Wang Yanling , Forson Kobina , Yin Zichen , Guo Baoyu , Liu Junyi 
Published: October 2019

Abstract
Guar gum and its derivative based-gels cross-linked with boron have been used in hydraulic fracturing for decades. In order to achieve gel strength requirements, conventional fracturing requires the use of a large amount of thickener and cross-linking agent, which results in more residue and difficulty in the recovery of permeability. At the same time, the gel can be used to achieve the best thermal stability in a high pH environment. Therefore, we proposed a highly efficient organoboron nanocellulose cross-linker for low polymer loading fracturing fluids.
Nanocrystalline cellulose (NCC) resulted from sulfuric acid hydrolysis of cellulose microciystalline. Boron-modified nanoparticles were synthesized by one-pot reaction as nano boron cross-linker (NBC). Nanocrystalline cellulose (NCC), (3-Aminopropyl) triethoxysilane, Organic boron (OBC) was mixed at a ratio of 1:4:4 and stirred at a constant temperature of 85°C for 5 hours. The presence of surface modification was shown with FTIR spectroscopy and the particle size was characterized by Transmission Electron Microscopy. The microscopic morphology of the NBC crosslinked gels was observed by SEM. The changes in gels rheology in different pH environments were investigated. In addition, the effect of mass ratio of NCC and OBC on the rheological properties of NBC crosslinked HPG gel was also investigated.
The results of FTIR spectroscopy illustrated OBC was bonded onto the surface of NCC by B-N bond. The particles have a large aspect ratio with a diameter of 5-20 nm and a length of 50-300 nm. NBC cross-linked 0.25 wt.% gels exhibited excellent rheological properties at 90°C. When the pH was increased from 7 to 11, the viscosity of the NBC crosslinked gels increased from 56.64 mPa·s to 348.7 mPa·s, and as the pH continued to increase, the viscosity of the gels began to decrease. The gels maintained a shear rate of 170s-1 at 90°C and the residual viscosity after shearing for one hour was higher than 50 mPa·s, which is in accordance with the requirements of fracturing construction. Due to the thermal stability of the NBC cross-linked-gels, pH was affected. The NBC cross-linked-gels had different microscopic morphology at different pH and the microstructures become more complex at higher pH.
NCC is a kind of natural macromolecular materials made from microcrystalline cellulose, which has the properties of abundance, biodegradability and low price, and has greater economic advantages compared with other nanoparticles. The NCC prepared by sulfuric acid hydrolysis has good dispersion due to electrostatic repulsion. The NBC crosslinker has excellent cross-linking properties, which may provide a possible solution to reduce the amount of cross-linking agent used, thereby reducing formation damage.
Unlocking Depleted Sandy Reservoir Potential using ESP Improvement in Cinta Field
Authors: Herlanda Maulidia , Afi Futiha Nur , Dondo Maximilian Stef , Zhafira Kautsar , Bagus Satrio Sumatri Anggi 
Published: October 2019

Abstract
The Cinta Field is one of fields in Offshore South East Sumatera Block which discovered on 1970. The first well development was in 1971 in Talang Akar Formation (TAF) which consist of Zelda and Gita member. Peak production was 70,721 barrel oil per day on Jan, 1977. Initial reservoir pressure was 1488 psi and current reservoir pressure is 500 psi. Nowadays, Cinta field has produced 4,300 barrel oil per day and average water cut 96%. The production challenges in TAF are depleted reservoir pressure that leads to sand and gas production. Artificial lift method applied in Cinta Field is Electric Submersible Pump (ESP).
Sand production can create problem in ESP that lead to trip off overload or the worst is shaft broken. Loss of production due to waiting barge to replace the broken ESP will occur. Mechanical sand control has been applied such as gravel pack, expandable sand screen and standalone sand screen to prevent sand produced through ESP. Most of them have failed due to massive sand production. Re-sand control can be alternative solution for this problem, but it can't be done due to low reservoir pressure and most of sand control will lowering productivity index of the wells. Immediate solution of this situation will be improvement of ESP itself. ESP will adapt with sand production situation by improving material and design of pump stages.
This paper will present improvement run life of ESP by using new type ESP that is more suitable in sand production situation in Cinta Field.