bluuebunny/crossref_metadata_2025_split huggingface dataset:
Success Story of Sustaining Production of Shallow Sand Reservoir with Screenless Fracpack Treatment in Mangunjaya Field
Authors: Putranti Andretiana , Yudis I Putu , Nasution Sakti Lail , Wijaya Rio , Giansyah Mohammad Zuly , Sarwono ArdhitoWirawan , Dusyanto Erwin Dicky 
Published: October 2019

Abstract
The wells in Mangunjaya field are known for high basic sediment (BS) production (more than 0.5%) and the need for frequent well interventions to cleanout formation sand production. A Screenless Fracpack operation was recommended as a solution for optimizing oil production by means of either the lifetime of the well or the maximum tolerance of BS% to reduce well intervention costs.
Four of the producing oil wells in the Mangunjaya field were treated with Screenless Fracpack treatment in 2018 as part of a well production maintenance process. This was not only to sustain oil production with the least possible intervention, but to reduce the basic sediment percentage to the range of 0.2 to 0.3% where it could be effectively lifted by beam pump and/or PCP pump.
The wells were producing from the Palembang Sand Formation with a total perforation interval of 3 - 17 m per well. The bottomhole pressure and temperature of the Palembang Sand Formation were 257 - 301 psi and 108.5 - 121°F. This formation is a shallow sand with the depth of the formation of 200 - 350 meters (TVD) and the formation has good permeability reservoir in the range of 50 - 300 mD.
The job size of the Screenless Fracpack was 30.3 to 37.7 Klbs (34.4 Klbs average) with a resin concentration of 3.75 gal per 1,000 lbm of ceramic proppant. The pumping rate was 12 to 16 bbl/min with surface pumping pressure of 500 to 1,000 psi. The wells were shut-in for 1 – 2 days to let the gel break and to let the resin cure.
Before the Screenless Fracpack treatment, the well production lifetime was around 90 days with two times well intervention with hoist (to cleanout the sand and repair the pump), the wells were producing 20 - 55 BOPD with more than 0.5% BS average. After the Screenless Fracpack treatment, the production lifetime increased. The wells were producing for more than 120 days with zero well intervention and production increased from 61 to 95 BOPD with 0.2 to 0.3 BS% lifted at higher rev/min of beam pump or PCP pump. This means that oil production was increased by 11 to 375% while the BS% was decreased by 33 to 93%.
First Application of Ultrasonic Technology in South East Asia: Breakthrough Case Study in Field T - Opening Doors for Alternative Stimulation Methods
Authors: Chang Claire Li , Spenger Oliver , Amran Amierul , M Khalil M Idraki , M Ariffin M Hafizi , Balakrishnan Dinesh 
Published: October 2019

Abstract
When a well has been diagnosed with formation damage, the norm is for operators to propose reservoir stimulation via acid/solvent pumping. In Field T, located offshore Bintulu in Malaysia, mineralogy understanding is limited as cores available only represent a few reservoirs. For those reservoirs which do not possess representative cores, it is a risk to prescribe any chemical. Historically, acid and solvent stimulation do not hold a good track record in T field. Hence, it is essential seek other stimulation methods that do not involve the requirement for mineralogy.
The UST (ultrasonic stimulation) technology operates on the concept of ultrasonic waves combined with low frequency waves breaking nearby damage up to 1000m into the reservoir. The resonator is conveyed by E-line, hence, possessing a smaller footprint as compared to mobilization of a pumping unit and chemical tanks. Platforms in Field T are small, hence, bringing a pumping package onboard will require hiring a barge due to limited deck space. Seemingly, operational risks are reduced as there is no need for manual chemical handling. The selling point of this technology is minimal well downtime as the stimulation can be performed on a live well, which further reduces possibility of damaging formation during stimulation due to secondary chemical reactions.
UST was piloted on 2 wells in Field T: Well X and Y. Well X showed an initial 30% gain post stimulation. Well Y was showing signs of clogged gas lift valves. Post operation observed pressure communication between tubing and casing which suggests that UST successfully broke the wax that was clogging the gas lift valves. A takeback from this project would be to not only stimulate the target reservoir, but to also stimulate the tubing walls and gas lift valves if there are any suspected valve plugging in the well. This paper will describe the technology that was used to stimulate the well in an environmentally friendly, non-invasive method. For fields with limited mineralogy data and deck space, it is recommended to explore an alternative stimulation method, such as UST, on the wells.
Modeling Interwell Interference: A Study of the Effects of Parent Well Depletion on Asymmetric Fracture Propagation in Child Wells
Authors: Guo Xuyang , Ma Junxiu , Wang Song , Zhu Tao , Jin Yan 
Published: October 2019

Abstract
Interwell interference has been widely observed in the development of unconventional reservoirs. It describes the phenomenon that legacy production of parent wells impact the completion quality of child wells, which in return changes production performance of both parent and child wells. This work models pressure and stress evolutions caused by parent well depletion and the corresponding asymmetric child well hydraulic fracture growth.
The study presents a 3D finite-element-based fully coupled flow and geomechanics model that simulates the poroelastic behaviors of pressure and in-situ stress evolutions, and a hydraulic fracture model. Based on the simulated pressure and stress heterogeneities at and around child wells, the complex and asymmetric fracture patterns for the child well can be quantified. In the study, with several candidate child-well locations placed away from the parent well, the stress and pressure evolutions along the child well are observed to be asymmetric. Numerical investigations show that production timing of parent wells, in-situ stress contrast, well spacing, parent well fracture geometry, and the design of perforation clusters along the child wellbore are key parameters affecting the asymmetric fracturing of child wells. Specifically, prolonged parent well production, small in-situ stress contrast and close parent-child well spacing lead to significant asymmetric stress and pressure evolutions along the child well, and consequently contribute to the asymmetric fracture wing growth during child well completion. Effects of the parent-well fracture geometry on asymmetric child-well fracture wing growth are only noticeable when the well spacing is small. This work identifies key parameters in a typical interwell interference case and studies their effects on asymmetric child well fracturing. The work serves as a reference for the avoidance of child-well underperformance, which is widely observed in many major shale plays.
Successful Monetisation of an Extremely Thin Oil Rim and Slanted Contact Reservoir, Offshore Malaysia, through Emerging Technologies and Innovative Concepts
Authors: Ahmad Tajuddin Nor Baizurah , Dan Hui Xuan , Tusimin Fuziana , Kawar Saraton , Riza Feisal Sheikh M. , Wahid Ali Nurul Athirah , M. Shah Jamari , Riyanto Latief , Hussain Mansoor , A'Akif Fadzil Nurul Aula , Sakdilah M. Zaki 
Published: October 2019

Abstract
The scope of the paper is to share a case study of a successful horizontal well completed within an extremely thin oil rim of ~10ft with bottom water. This paper highlights the differentiating activities undertaken to deliver the well despite the challenges of extremely thin oil rim, strong water drive and uneven current fluid contacts.
Prior to drilling this well, attempt was made to mitigate the uncertainty regarding the current gas-oil contact (GOC) and oil-water contact (OWC) by carrying out cased-hole logging in some of the adjacent wells, and re-sequencing and re-optimizing the location of two of the wells targeting the reservoirs below. This obviated the need for the pilot hole and thereby resulted in a cost saving of ~USD 1Million. Furthermore, the dynamic simulation model was updated to create a fit-for-purpose model with the latest OWC and GOC, so as to be able to test various trajectories.
While drilling, the well was drilled with real-time reservoir mapping-while-drilling technology and integrated with real-time reservoir characterization, fluid typing and trajectory modification, while maintaining Dog Leg Severity (DLS) below 3 deg/100ft for the ease of completion run.
Completion was then optimized with viscosity-based inflow control orifices. Post drilling, dynamic and well models were calibrated to the actual results to determine optimum production rate for the well life.
The horizontal well was successfully navigated and optimally placed in the extremely thin oil column. Tilted contacts were encountered in the targeted subunits where actual current contacts came in ~20ft shallower at heel and ~10ft deeper at toe compared to prognosis. Consequently, the heel landed at a 5ft stand-off from water, and the toe landed 18ft stand-off from water and 6ft stand-off from gas.
The well was successfully unloaded and tested at a controlled oil rate of 2887 bopd, 50% higher than planned target.
This paper presents the entire process from well planning until well production tie-in. This was achieved through the integration of subsurface understanding with the utilization of the appropriate technology. Finally, the management's trust in the capability of the team members ensured deliverability of the target production rate and the consequent booked reserves.
DrillersAssist; An Integrated System for Real-Time Drilling Process Automation
Authors: Mirhaj Ahmad , Sandrib Bjarne , Lien Morten 
Published: October 2019

Abstract
Drilling automation is a rapidly developing area of technology that is seeing growing interest within the drilling industry. MHWirth as one of the world-leading providers of complete drilling rig packages including the equipment software systems has been focusing on developing a set of different smart modules in order to perform more efficient operations.
This paper describes the MHWirth's DrillersAssist. It is a Smart Module that assists the driller with downhole operations. It offers automation of well construction sequences, and protective limits safeguarding the well. This helps with efficient and consistent well construction.
All functions and protective limits in DrillersAssist are configured by the operator based on input from the well plan, mud logger and other sources.
It contains three drilling sequences; mud pump start-up, hole cleaning and friction test sequences.
DrillersAssist also provides several well protection functions. It is worthy to mention that the operator can easily override the protection if required due to operational reasons.
Thereafter the results of implementing DrillersAssisst on Transocean-Enabler rig for drilling operation of a well in Barent-sea will be presented. The results show its first pilot run had quite some cost reduction compared to when drilling operation performed without the use of DrillersAssist.
Unify Exploitation and Exploration Prospect to Revive Idle Marginal Offshore Brown Field in South East Sumatera, Indonesia
Authors: Waskito Lucky Bagus , Gunawan Heri , Nugroho Pranowo , Senoaji Wahyu 
Published: October 2019

Abstract
Located offshore South East Sumatera Indonesia, C-SY field is a structural trap with 4-ways dip closure and multiple reservoir targets with excellent rock properties, considered a marginal field and currently idle for 8 years. Challenges faced in reactivating C-SY field are high investments compare to other well service proposal and have limited reserves. The objective of this paper is to revive idle marginal offshore brownfield C-SY by increasing value of reserves and economics value. In order to do so, all prospects within C-SY area need to be assesed, including exploration prospects with high geological chance factor.
The evaluation process worked simultaneously by exploitation and exploration team. The exploitation team worked on re-estimate OOIP and reserves of existing reservoir by structural interpretation, reservoir characterization analysis using attributes, Decline Curve Analysis & Material Balance Analysis. While the exploration team worked on finding other reservoir prospects by doing prospect identification from 3D seismic analysis, structural play analysis, closure identification and migration pathway from kitchen to prospect area, calculate OOIP. Result from both teams were combined to estimate reservoir behavior and production forecast. The next step of evaluation was to create multiple cases of possibilities and calculate the economics to find the best and possible case with minimum calculated risk.
Collaboration between Exploitation and Exploration has lifted the value of C-SY idle marginal brown field, new structure has been found with promising reserves and initial production. Initial production C-SY field after the collaboration is 1,200 BOPD from previously 150 BOPD, while remaining reserves increase 3 times higher up to block expiration contract in 2038.
Developing marginal offshore mature asset is a risky business, especially considering high volatility in oil prices. Collaboration and technology are vital to escalate the economic value and achieve higher recovery factors. Application of the multidisciplinary methods was considered as an appropriate way to approach and manage a complex marginal mature field redevelopment.
Innovative Approach to Production Optimisation Using Customised Integrated Surveillance Approach
Authors: Kumar Pankaj , Affeld Christian , Zdenkovic Nick 
Published: October 2019

Abstract
This paper presents the innovative way of Production Optimisation using fit for purpose customized Integrated Surveillance approach which helped to manage a complex field in West Africa in a very effective manner in the low-cost environment. Integrated surveillance approach, workflow overview and the best practices are provided to demonstrate effective field management.
An integrated surveillance approach was based on the fundamentals of addressing day to day challenges in a seamless and efficient manner. To enable this, a customized IST (Integrated Surveillance Tool) and standard workflow was developed to meet the requirements. The IST was tailored specifically towards making the most relevant data available to the evaluation team. IST acted as a single source to fetch all the critical data relevant to wells and key process components.
All critical data were then integrated and reproduced in a way to enable time effective decision making. For a selected well, relevant information was just a mouse-click away; this include the well completion, geological cross-sections, production test data, lift gas response curve, facility operating envelope, actions log, wells follow up document etc. Thus, detailed analysis could easily be carried out in one application. The IST allows extracting and updating wells and facility operating envelopes, performing exception-based surveillance, performing wells ranking either on a cluster or full field basis, performing lift gas optimum allocations on a subset or field level basis. In the regular optimization forums, IST was used to analyze wells per cluster, facility performance and integrated system to generate opportunities and quick actions to generate easy production gains. Workflow and processes are streamlined for effective time management.
The integrated surveillance approach enabled improvement in production gains in the order of about 20% through identification of issues, solutions and opportunities in a fast and efficient manner; such as bean-up, choke changes, gas lift optimization, creaming high GOR or high WC wells, zone changes etc. in an effective way.
An integrated and systematic approach to Well, Reservoir and Facility Management still represents a challenge in the industry; however, development and usage of customized integrated surveillance approach showed that the processes can be simplified and made more efficient to maximize production.
Application of Exploratory Data Analytics EDA in Coal Seam Gas Wells with Progressive Cavity Pumps PCPs
Authors: Saghir Fahd , Gonzalez Perdomo M. E. , Behrenbruch Peter 
Published: October 2019

Abstract
Artificial lift methods typically drive Coal Seam Gas (CSG) wells, and Progressive Cavity Pump (PCP) is the preferred method of lift with Australian CSG operators. CSG wells in Australia are typically equipped with necessary instrumentation and automation systems to provide real-time data gathering for monitoring and control purposes. Real-time data gathered from CSG wells presents an opportunity to better understand PCP performance by identifying anomalous pump behavior.
However, before undertaking any real-time analytics exercise, it is pertinent to carry out Exploratory Data Analytics (EDA) to understand time series data behavior and extract relevant features; and this exercise is particularly important with multi-variate data sets. Obtaining significant data features from multivariate time series data can help define which analytics and machine learning methods could be exploited to analyze PCP performance in near real time.
This paper will discuss EDA methodologies that can help streamline time-series data normalization and feature extraction techniques. A three (3) year time-series dataset, gathered from forty-two (42) CSG wells, will be used to showcase EDA methodologies utilized as part of this research. All EDA activities covered in this paper are based on the Python programming language and its supporting libraries.
The Application of Drill Cuttings to Evaluate the Fracability in Unconventional Shale Gas Resources
Authors: Shi Xian , Jiang Shu , Wang Zhixuan , Xiao Dianshi , Sun Xiaofei 
Published: October 2019

Abstract
Selecting a good fracturing candidate that can maximize the complex fracture network in advance is beneficial for enhancing the fracturing effectiveness and the economic development of shale gas reservoirs. Brittleness is generally used to evaluate the capability of complex fracture networks by using critical mechanical parameters, but these parameters must be acquired from well logs and time-consuming triaxial core-scale mechanical tests. However, considering the physical and chemical instability of shales, standard-sized core plugs are difficult to obtain in some zones of interest. Thus, the analysis of drill cuttings by the combination of SEM/EDS (scanning electron microscopy-energy dispersive spectrometer) analyses and grid nanoindentation was used to replace conventional standard measurements on high-quality sized cores. A significant advantage of this technique is that drill cuttings can be collected from most wells. Furthermore, in contrast to traditional tests, the petrophysical and mechanical properties of shales can be characterized simultaneously. Thus, a comprehensive brittleness model can be established based on the mineral brittleness and mechanical brittleness. Experimental results demonstrate that the integration of grid nanoindentation and the deconvolution technique can provide reliable estimations of the homogenized Young's modulus and Poisson's ratio, while EDS mapping can provide accurate mineral compositions of the indentation area. The method is successfully applied to evaluate the brittleness of a shale gas well in a shale gas field in China, which demonstrates that this method is a fast and cost-efficient way to evaluate the brittleness of shale gas formations with a small volume of rock samples.
Establishing Proper Abandonment and Site Restoration Strategy to Reduce Uncertainty in Developing Mature Offshore Field: A Case Study of ONWJ Field in Indonesia
Authors: Sajjad Farasdaq Muchibus , Hadi Prasetyo Abraham , Chandra Steven , Wijaya Budi Rivai , Naja Savinatun 
Published: October 2019

Abstract
Abandonment and site restoration (ASR) is one of the responsibilities of Oil and Gas Company for the country where it operates. The ASR covers plug and abandon (P&A) of wells and dismantling of surface equipment in order to restore the environment as close as possible to its original state.
Current practices in Indonesia's oil and gas business does not put P&A as one of the top priorities, compared to other engineering aspects in petroleum engineering. Therefore, P&A is sometimes regarded as a formality.
A case study where long term oil and gas exploration and production with unique rock mechanics in Offshore North West Java (ONWJ) Area has caused subsidence and inherently leading to both production operation and well integrity issues. Several issues namely casing deformation and detachment from main casing strings have been observed and is likely to put harm to oil and gas production in ONWJ Area. Casing issues such as buckling and crumpling, as well as the presence of micro cracks will present complications in safely plugging and abandoning the affected wells.
Recommendations based on current practices around the world as well as mitigation solutions done in ONWJ Area such as mechanical stress and/or strain release combined with well condition evaluation and monitoring is maximized as an input to properly design safe and cost efficient P&A strategy for complex, marginal, and offshore wells with integrity issues. This research is aimed to become a benchmark for future uses of P&A not only in ONWJ area but also in Indonesia.