bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mono Ethylene Glycol Regeneration System Upgrade
Authors: Kim Jonghyun , Scalea Paolo , Kim Jeongmoon , Kang Seongyoon 
Published: October 2019

Abstract

Objectives/Scope
This paper covers the Shwe Offshore Platform (SHP) MEG Regeneration System upgrade works implemented to reduce excessive MEG losses and improve operation of the System.

Methods, Procedures, Process
The SHP MEG Regeneration System processes MEG used in the topsides for hydrate inhibition in the Low Temperature Separators (LTS) and at the four subsea wells. Since start-up of production in 2013, SHP has suffered from excessive MEG losses and operational difficulties. Later in the field life, MEG injection to subsea wells was discontinued due to contamination with salts from formation water, and Kinetic Hydrate Inhibitor (KHI) injection was introduced. Extensive evaluation of data, laboratory tests and field trials were carried out to investigate the causes of the excessive MEG consumption and operational difficulties. The upgrade of the MEG Regeneration System was finally completed and put in service since May 2018.

Results, Observations, Conclusions
The followings have been identified as the direct causes for MEG losses and operational difficulties; Poor efficiency of Glycol-Glycol Heat Exchangers (HEXs), causing low operating temperature of the Rich MEG Flash Drum and poor condensate/Rich MEG separation, resulting in MEG losses via Flash Drum condensate outlet.Excessive condensate in the Rich MEG reaching the Reboiler and resulting in contamination of the Lean MEG and downstream section (injection spray bars).Low water loading in the MEG Regeneration System resulting in lack of reflux and MEG losses via Reflux Drum.MEG carryover from LTS to the Export Gas Compressor (EGC) Suction Scrubbers, caused by foaming in the LTSs.
In order to resolve the issues above, a number of modifications were implemented. New Glycol-Glycol HEX and a Liquid-Liquid Coalescer Filter were installed to provide better separation of condensate from Rich MEG. Also re-routing of the EGC Suction Scrubbers liquid outlet back to the MEG Regeneration System to recover the carried over MEG.
Significant reduction of MEG losses was achieved, in the range of 70%, and overall system performance has improved. The main outcome of such improvement is that the condensate content in Rich MEG has been significantly decreased to below 500ppmV from above 1vol% due to the increase of Rich MEG Operating Temperature in Flash Drum and introduction of the Liquid-Liquid Coalescer Filter.

Novel/Additive Information
This paper was written to describe the method used for resolving the problems with MEG losses, excessive condensate in the Rich MEG, and MEG carryover. It also explains the data evaluation, preparation, execution, and the results of the MEG Regeneration System Upgrade work.
Meeting the Strategy of Onshore Petroleum Exploration Based on Statistical Analysis of Operating Cost and Commercial Reserves in Indonesia
Authors: Abdul Azizurrofi Ahmad , Setya Buana Yosef , Bramono Triadi 
Published: October 2019

Abstract
In early 2016, oil price has fallen to its lowest level (30.32 US$/bbl) over the last 12 years. Since then, petroleum exploration and exploitation activities are decreasing worldwide due to high production cost and low oil prices.
As of December 2017, there were 431 Projects or PODs approved by government of Indonesia and the 327 of them were PODs that located in onshore area. This paper will evaluate and analyze the distribution of commercial reserves per projects and the operating cost to help Contractors to find the onshore area in Indonesia that has the highest commercial reserves and the lowest operating cost.
The purpose of this paper is, to divide the geographical areas of Indonesia into 5 different areas (Sumatera, Java, Kalimantan, Sulawesi and Papua)). Then, to collect the data that related with number & location of Projects (POD), commercial reserves and operating cost and then the project reserves (MMBOE/project) and project operating costs (US$/boe) are calculated and distributed to those aforementioned areas.
Based on the analysis and mapping of Petroleum Operating Cost and Commercial Reserves of 327 onshore Projects (POD), Sulawesi had the highest commercial reserves (64.00 MMBOE per Project) and Sumatera had the lowest commercial reserves (7.20 MMBOE per Project). As for the operating cost, Papua had the lowest operating cost (2.50 US$/BOE) and Kalimantan had the highest operating cost (10.10 US$/BOE) which remained lower than the current oil price (49.52 US$/BBL, average oil price January – July 2017). These analyses showed that the onshore area in eastern of Indonesia tends to have low operating cost and the high commercial reserves, which consequently mean that the onshore petroleum exploration and exploitation activity should be done by contractors in eastern area of Indonesia.
Finally, this paper is expected to provide contractors a quick look at oil and gas industry in Indonesia especially at onshore area and guide them to choose which onshore area of Indonesia to explored and also help them create their petroleum exploration strategy in Indonesia by considering on this information.
Digitalizing Performance Management with Business Analytics and Risk Based Planning
Authors: Okasha Qutaiba , Aladasani Ahmad , Al Dushaishi Mohammad F. , Ameen Ali , Nygaard Runar 
Published: October 2019

Abstract
A case study is presented in this paper that introduces a novel approach to Performance Management (PM) in an Exploration and Production Development Company (E&PDC). Typically, performance is measured at a functional level without sufficient attention to the validity of the Strategy, and the efficiency of the organization, or its leadership. Business analytics, and risk-based planning is used to improve the application of the business Strategy in an E&PDC. The case study described in this paper examines the Strategic performance, and the organization’s efficiency as part of the Performance Management system. Data Analytics was conducted on consolidated 12 years historical performance metrics to identify, the Health of the Strategy, correlations of different Performance Management metrics, and, leadership efficiency. Strategic outlook was developed using multi variable regression to slice, and dice business performance profiles, assess risk, as well as opportunity. Risk based planning is then conducted on the statistical results to quantitively rank the E&PDC enterprise risks. The results indicate significant diversity in the organizational structure, and associated workflow. Consequently, the functional performance in the E&PDC is variable, and is often downgraded by incomplete workflow, and inadequate organization efficiency. However, the shortfalls of the business performance whether in organization, or workflow presents a wealth of information that can be readily used to improve business performance. Therefore, work in this paper provides the opportunity to improve cost per barrel by up to 20%, a reduction of up to 30% in capital investments, and a up to 25% decrease of man-hours required to carry out core business functions. The benefits of aligning organization capabilities with the Strategy, and revisiting policy is underlined in this paper. The economic viability challenges facing the oil and gas sector today require a lean approach to manage business liabilities. This can only be achieved with measurement of functional, organizational and strategy, performance and the development of risk-based business plans that prioritize annual business plans.
Evaluating the Impact of Market Variability on Reservoir Behavior and Economics
Authors: Browning Jim , Gorell Sheldon 
Published: October 2019

Abstract
Market behavior is not always predictable: commodity prices can rapidly change; political and corporate strategies are dynamic. This variability in market forces may drive immediate and significant changes to the production plan. Unfortunately, large changes to production rates (up and down) can cause formation damage, permanently affecting reservoir productivity and reserves. Consequently, responding to market variability requires informed decision making and an effective communication process. Each reservoir has unique characteristics. Learning from the effects of operational changes improves the understanding of the reservoir and can substantially improve the decision-making process. Reservoir surveillance and simulation provide the ability to analyze, model, and forecast reservoir behavior throughout its productive life. This data acquisition and analysis provides insight necessary to determine mitigation and repair strategies as issues arise.
This paper reviews market drivers for different types of operating companies and associated operational responses. Reservoir impacts of various operational changes (production rates, methods and treatments) are described. Information sharing and effective communication across the organization are necessary for the effective development of a petroleum resource. To address this, common issues and a recommended decision making process are provided.
Hybrid Nano Acid Fluid Pulsed with Electrokinetic to Stimulate Tight Carbonate Reservoirs: A Novel EOR/IOR Method
Authors: Kim Minkyun , Haroun Mohammed , Rahman Md Motiur , Kobaisi Mohammed Al 
Published: October 2019

Abstract
This study characterizes the impact of hybrid nano-acid fluids (HNAF) to improve oil recovery from tight carbonate reservoirs. While acidizing creates continuous channels (wormholes), wettability alteration takes place by nanoparticles in penetrating through the tight pore throats and adsorbing on the surface of pore wall. In addition, it is validated that the application of HNAFs with pulsed electrokinetics (EK) effectively stimulates the tight formation, which is being investigated by dual energy computed tomography (DECT) scan, showing efficient wormholes. Methodology is divided into two parts. The fisrt part is to identify optimum concentration of hybrid nano-acid fluids by conducting IFT measurements. The second part is to verify the combined effect of hybrid nano-acid fluids with electrokinetics and relative contribution of acid, nanoparticles, and electrokinetics by conducting spontaneous imbibition tests, core flood experiments, and zeta potential data.
Selected HNAF formulations, such as SiO2-Acid (HNAF1), Al2 O3-Acid (HNAF2) and ZnO-Acid (HNAF3), produced a significant IFT reduction under HPHT conditions from 18 dyne/cm (formation water and oil) to 3.14 dyne/cm, 2.89 dyne/cm, and 4.14 dyne/cm respectively. When conducted with sequential application of EK, HNAF1 showed higher performance compared to HNAF2, followed by HNAF3, in terms of displacement efficiency (DE). During pulsed simultaneous application of EK, HNAF1 showed higher performance followed by HNAF3 and HNAF2. The DE and PE averaged at 9% and 180% during sequential application. The displacement efficiency recorded a significant increase in the case of simultaneous versus sequential application while requiring 27% less pore volumes injected. The zeta potential verified the coreflood (CF) ranking order through matched shifts in zeta potential before and after CF, which confirms a drastic alteration in wettability post flooding.
The summary of research presents promising potential to overcome the limitations reported from the previous studies, and improved the understanding of the application of HNAFs in tight carbonate reservoirs. This integrated study has assisted in successful formulation of HNAF assisted with the EK in lab scale.
Improving Horizontal Well Performance with Bottom Feeder Intake on Electric Submersible Pump in Gassy Wells, Offshore North West Java
Authors: Puspita Clarissa Tyas , Luciawaty Mery , Wirasupena Harisza 
Published: October 2019

Abstract
Oz is an offshore oil field with Electric Submersible Pump (ESP) as the main artificial lift system. Gassy well condition becomes a key challenge in this field as some ESP wells trip due to pump gas locking which leads to production deferment and ESP failures. The exploration for solutions to improve well performance by avoiding gas-locking conditions has gone through a steep learning curve and many adjustments since ESP firstly installed in Oz field. Starting from widely used conventional gas handling equipments such as gas separator and gas handler to application of multiphase pump on the ESP system. But none of those equipments have effectively eliminated gas-locking condition in some wells. This paper will present a new approach at Oz field to improve well performance by implementing bottom feeder intake application on electric submersible pumps in gassy well.
To analyze this problem, well production simulations were performed and found out that flow pattern on the lateral section or below the ESP completion was slugging at some well conditions. Due to the slugging flow pattern, the fluid hold up in the annulus might be reduced up to 30%. A large amount of gas volume will enter the pump when the slug reaches the pump intake. In such a case, neither gas separator or gas handler is able to separate the gas or condition the flow before going into a pump, which leads to the gas-locking condition in the pump. Bottom Feeder Intake (BFI) was proposed as a unique and versatile solution to handle gas when slug flow pattern occurs in ESP wells, which effectively reduces gas-locking condition on ESP and subsequently improves well performance on those problematic wells.
Electric submersible pump with combination of gas separator and bottom feeder intake were first successfully installed in several wells in 2016 and currently are still running. The combination of bottom feeder intake and gas separator have been progressively installed on some problematic wells since then. This application significantly minimizes gas-locking problems, avoids cyclic shutdowns, increases ESP service life, reduces deferred production activities and gives opportunities to increase the production from ESP wells. Through well production simulation and analyzing the effect of fluid flow pattern below ESP completion to pump gas-locking symptom, bottom feeder intake has been chosen as an effective solution to minimize gas-locking in gassy well.
Present Situation and New Problems about Deliquification of the Four Major Gas Provinces
Authors: Jia Min , Li Nan , Zhang Jianjun , Shi Junfeng , Li Jun , Cao Guangqiang , Wang Haoyu , Wang Yun , Zhang Yi , Liu Yan , Wei Meiji , Wu Cheng 
Published: October 2019

Abstract
More than 80% of gas reservoirs in the four major gas provinces in China (Changqing, Southwest, Tarim and Qinghai) are producing water, and the gas reserves involved account for more than 75% of the total.
On the basis of continuous monitoring of water production and deliquification techniques in the provinces, the following observations are achieved. Firstly, the severity of water production in the four provinces is getting increasingly higher, and big challenge is confronted in striving for stable gas production in the fields. The proportion of water-producing wells increased rapidly from 38.1% in 2011 to 49.7% in 2018, resulting in dramatic decrease in single-well gas production (by 20% -- 99%). Secondly, deliquification is the primary technique for stable gas production and improved gas recovery in water-producing gas fields. The number of wells where deliquification technique is applied accounts for 94.68% of the total gas producing wells. The incremental production by deliquification accounts for 63.56% of the total increment. Foam deliquification is the major deliquification process applied in the four provinces. In 2018, the number of wells where foam deliquification was applied accounted for 66.43% of the total number of wells with deliquification, and the incremental production accounted for 55.20% of the total increment by deliquification. The techniques such as plunger lift and velocity string deliquification are also being applied more and more.
Three new problems are identified with deliquification techniques in the four provinces at present. Firstly, with the maturing of the fields, there will be more and more strippers with some of them approaching to the end of their life, and foam deliquification will no longer be competent as the major deliquification process. Secondly, as a deliquification process for strippers, plunger lift has a big potential of wide application, but there are still many problems to be solved with it. It is urgent to systematically monitor and analyze its performance, with proposals to be put forward on the relevant researches and its dissemination. And thirdly, Tarim gas field is facing the fact that water production gets more and more serious, and the gas production is drastically decreasing. What is even worse, the current method has poor effect on water control, so it is urgently imperative to carry out comprehensive studies on water production and overall water-control countermeasure.
By literature investigation and on-site analysis for nealy a decade, it is found that the operation parameters of 33% of the strippers fall beyond the applicable range of foam deliquification. The effective solution to this problem is to disseminate the application of plunger lift to meet the constantly increasing demand because of more and more wells' deteriorating to be strippers.
Safeguarding Well Integrity through Vigilant Sand Production Monitoring and Surveillance in Digital Field
Authors: Mohd Shabarudin Ezza Shazana , Mokhlis Mohamad Mustaqim 
Published: October 2019

Abstract
Prevention is better than cure is the right phrase to express how important sand production monitoring and surveillance to protect well integrity which consequently help securing environment, people, asset and also reputation without causing unnecessary restrictions to the production performance. This paper showcases the benefits gained from utilizing an automated Digital Integrated Operations System, or "IO" to enhance the existing Sand Monitoring and Management (SMM) workflow.
Sand production will impose significant impact and key failure are mostly related to erosion and sand accumulation. Reactive management approach can be implemented in a faster manner should we have good surveillance. The IO was designed to provide critical information on the historical and current status and operating conditions of wells, production and injection equipment, as well as daily production and injection volumes based on data fed from the thousands of transmitters installed at the plant. The system is used for different applications related to production surveillance and optimization, and also includes sand management as a core module. For this purpose, it utilizes the SMM workflow by enabling visual monitoring of well sand count data and compliance to well sampling plan in the IO platform, and by performing daily computation of erosional rates together with remaining wall thickness on surface flowlines - achieved by combining live well parameters with latest sand count data, latest well test and erosion rate.
Upon stringent monitoring, two (2) wells were identified by IO to be under high risk and quick action was taken to manage the risk. From IO, number of times that each well had been categorized under severity were then be validated by checking in the input data. From well monitoring and surveillance, flowing tubing head pressure (FTHP) were seen lower than trending and bean size had been fully opened. Knowing that the well is prone to be producing high amount of sand and expose to downhole integrity issue, the sand production must be controlled before it reaches to the surface.
The immediate action was to choke down the well, monitor the FTHP, evaluate well test performance trending and most importantly increase the frequency of sand count. After doing so, the team observed that erosion rate has been reduced below the limit and sand count was also reduced. Simple action can be taken if we know what is the root cause in a timely manner. All this will be possible through IO. Visualization had been transparent, communication was enhanced, and collaboration boosted towards safe operation.
Identifying High-Performance EOR Surfactants Through Non-Destructive Evaluation of the Phase Behavior Microstructure
Authors: AlSinan Marwah , Kwak Hyung , Salomon Marques Debora , Kaidar Ziyad 
Published: October 2019

Abstract
Surfactant screening for enhanced oil recovery involves studies of fluid-fluid and fluid-rock interactions to optimize the surfactant formulation for the reservoir of interest. In this paper, we utilize low field nuclear magnetic resonance (NMR) technology to monitor the phase behavior microstructure of fluid mixtures developed for high salinity and medium-range temperature conditions. A surfactant mixture of unknown composition was selected since it was developed for high salinity and temperature reservoirs.
Surfactant performance was monitored over 20 days using phase behavior bottle tests. Crude oil was mixed with surfactant solutions of different salinities to study the different emerging phase behaviors. Salinity scans were carried out using synthetic seawater. Also, samples were aged at 25 and 68 °C to monitor the progression of emulsion phase behavior. In addition to visual inspection, NMR measurements, in the form of 1D brine profiles along the samples, were conducted to detect the observed dispersed phases throughout the aging process and evaluate the associated oil-water interfacial tension (IFT).
At both temperatures, all samples formed water-in-oil (W/O) and oil-in-water (O/W) emulsions, except for the 4.5% salinity sample at 25 °C. Also, at 25 °C, both types of emulsions were shrinking with aging while forming a secondary W/O emulsion in-between the two phases. On the other hand, at 68 °C, emulsion break-down was accompanied by the formation of a middle O/W emulsion for 3 and 4.5% salinities while a middle W/O emulsion was emerging in 7.5 and 9% salinity samples. For the 6% salinity sample, two types of secondary emulsions, W/O and O/W, were developing in the middle of the sample.
Low field NMR techniques provide a nondestructive and robust method of monitoring surfactant performance, including dispersed volumes, emulsion stabilization time, emulsion type and surfactant potential in lowering oil-water IFT. In addition, they are capable of microscopic phase behavior monitoring, which is not possible by conventional visual monitoring technique.