Day 2 Wed, October 24, 2018最新文献

{"title":"A Rigorous Yet Simple Technique for Coupled Reservoir and Geomechanics Simulation","authors":"R. Matsunaga, Seishiro Watase, K. Furui","doi":"10.2118/192045-MS","DOIUrl":"https://doi.org/10.2118/192045-MS","url":null,"abstract":"\u0000 Many applications in the petroleum industry require both an understanding of the porous flow of reservoir fluids and an understanding of reservoir stresses and displacements. Historically reservoir simulation has accounted for geomechanical effects by simple use of a rock compressibility. This assumption results in pore volume to change only with pore pressure. On the other hand, according to the poroelasticity theory, pore volume should change not only with pore pressure but also with confining stresses or volumetric strains induced by rock deformation. This difference in the governing equations poses a great challenge when coupling reservoir flow and geomechanics models.\u0000 In this study, we develop a mathematical expression that relates the pore volume compressibility used in the porous flow equation to poroelasticity parameters defined in the geomechanics model. Secondly, in order to implement consistent pore volume changes between the reservoir flow and geomechanics models, we derive a pore volume correction term for the porous flow equation, which accounts for volumetric strain changes and rock matrix deformation. As demonstrated in the paper, the correction term can be easily implemented in sink/source terms (or \"fictitious well\" term), which are readily available for most commercial reservoir flow models. With this simple implementation, virtually any existing commercial reservoir simulation models can account for geomechanical effects via modular coupling techniques.\u0000 In this work, we compare three different techniques for coupling reservoir flow and geomechanics. One technique uses an explicit algorithm to couple reservoir flow and displacements in which flow calculations are performed every time step followed by displacement calculations (i.e., One-way coupling method). A second technique uses an iteratively coupled algorithm in which flow calculations and displacement calculations are performed sequentially for the nonlinear iterations during each time step (i.e., Iterative partitioned coupling method). The third technique uses a fully coupled approach in which the program's linear solver must solve simultaneously for fluid-flow variables and displacement variables (i.e., Monolithic coupling method). Using Mandel's problem, example simulations are presented to highlight accuracy and computational efficiencies in these coupling techniques.\u0000 To the best of the author's knowledge, this is the first paper to present a coupling technique to consider rigorous geomechanical effects in the porous flow equations. The coupling method proposed in this study can be applicable for virtually any existing reservoir and geomechanics simulation models. The proposed coupling techniques are easily extended to multiphase flow and poroelastoplastic problems. All problems in this paper are described in detail, so the results presented here may be used for comparison with other geomechanical / porous-flow simulators.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130157111","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Effect of Fines Migration During CO2 Injection Using Pore Scale Characterization","authors":"F. Othman, Yamin Wang, F. Hussain","doi":"10.2118/192076-MS","DOIUrl":"https://doi.org/10.2118/192076-MS","url":null,"abstract":"\u0000 Recent laboratory studies have shown fines migration induced decrease in rock permeability during CO2 injection. Fines migration is a pore scale phenomenon, yet previous laboratory studies did not conduct comprehensive pore scale characterization. This study utilizes integrated pore scale characterization techniques to study the phenomenon.\u0000 We present CO2 injection experiments performed on two Berea sandstone samples. The core samples are characterized using nitrogen permeability, X-ray micro-computed tomography (micro-CT), Scanning Electronic Microscopy with Energy Dispersive X-ray Spectroscopy (SEM-EDS) and Itrax X-ray Fluoresence (XRF) scanning. The core samples were flooded with freshwater, then CO2-saturated water, and finally water-saturated supercritical CO2 (scCO2). To calculate permeability, the pressure difference across the core samples was monitored during these fluid injections. The produced water samples were analysed using Inductively Coupled Plasma-Optical Emission Spectrometry (ICPOES). After the flooding experiment, nitrogen permeability, micro-CT, SEM-EDS and Itrax-XRF scanning was repeated to characterize pore scale damage. Micro-CT image based computations were run to estimate permeability decrease along the core sample length after injection.\u0000 Results show dissolution of dolomite and other high density minerals. Mineral dissolution dislodges fines particles which migrate during scCO2 injection. Berea 1 and Berea 2 showed respectively 29% and 13% increase in permeability during CO2-saturated water injection. But after water-saturated scCO2 injection, both Berea 1 and Berea 2 showed 60% decrease in permeability. The permeability damage of the sample can be explained by fines migration and subsequent blockage. SEM-EDS images also show some examples of pore blockage.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"73 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124275081","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Mechanistic Modeling of Low Salinity Water Injection under Fracturing Condition in Carbonate Reservoirs: Coupled Geochemical and Geomechanical Simulation Study","authors":"Seyed Moein Hosseini, S. Kord, A. Hashemi, H. Dashti","doi":"10.2118/192038-MS","DOIUrl":"https://doi.org/10.2118/192038-MS","url":null,"abstract":"\u0000 The main problem during field scale implantation of low salinity water injection (LSWI) is the decline in injectivity versus time. Moreover, the actual mechanisms that result in incremental oil recovery are not completely known. In previous studies, the geomechanical effects have not been considered, and pore volume changed while bulk volume is still constant which in turn can bring uncertainty to the simulation results. In this paper, both geochemical and geomechanical models have been coupled with the flow model. For coupling geomechanical model, three equations have been solved simultaneously in each time step. Then, the geochemical model has been coupled by adding the necessary aqueous and mineral reactions and ion concentration of both formation and injection waters. Increasing the Ca2+ concentration in the injected brine cause a reduction in the ultimate oil recovery. Also, increasing SO42− concentration in the injected brine up to about 70 ppm, resulted in increased oil recovery, while increasing the concentration caused a reduction in oil recovery. Injection above formation parting pressure (FPP) is beneficial but, there is a high uncertainty during injection above the FPP that can affect ultimate oil recovery and net present value. The results of this study show that geomechanical and rock parameters have intensive effects on the simulation results and rough estimating them in the simulation process can result in major errors and uncertainties. Further, it is very important to precisely include the dominant mechanisms of low salinity or smart water process during simulation studies.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"134 3-4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116267201","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Supramolecular & Oil Displacement Fluid for Hydraulic Fracturing","authors":"Weixiang Cui, Honglan Zou, Chunpeng Wang, Jiang Yang, Jun Yan","doi":"10.2118/192146-MS","DOIUrl":"https://doi.org/10.2118/192146-MS","url":null,"abstract":"\u0000 This paper studied a new fracturing fluid based on a supramolecular complex between associative polymer and viscoelastic surfactant (VES). The combination of VES and associative polymer synergistically enhances the viscosity several times more than that of the individual components alone. The fluid system was optimized by experimental design. The microstructure of wormlike micelle and complex formation was verified by electron microscopy. The proppant transport test in a large-scale fracture simulator showed good proppant suspension ability. After fracturing, the nano- surfactant molecule in the liquid have a high surface energy, which can play a good oil displacement effect in the crack.\u0000 The fluid has 50% lower formation damage than that of conventional guar. The fluid was prepared with less additives and formed gel instantly, which can be mixed on the fly in the field. The gel can be completely broken with almost no residue. By flooding and [1]nuclear magnetic resonance experiments results, compared to the conventional fracturing fluid and water, oil displacement efficiency can be increased by 12% to 20%, more micro-pores in the oil and gas drive for higher pressure stimulation effect for tight oil reservoir. Field application of the new fracturing fluid in 10 tight gas wells showed the enhancement of gas production over 100%. The fluid has 20% lower friction pressure than that of guar fluid. Hence, the new supramolecular fluid is an effective fracturing fluid.\u0000 Supramolecular fracturing fluid provides a new fracturing system with less formation damage to fracturing operation. This paper will be beneficial to all engineers and technologists who are currently working at tight gas stimulation applications.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"212 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133999327","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimizing Sand Control Treatments Using Gauge Data","authors":"Samyak Jain, Philip Wassouf, R. Tibbles","doi":"10.2118/192094-MS","DOIUrl":"https://doi.org/10.2118/192094-MS","url":null,"abstract":"\u0000 While the importance of pre-job design has always been appreciated, detailed post-job evaluation of gravel pack execution data (both surface and downhole) is equally valuable as it provides a means to learn from past treatments, calibrate models, and improve future designs. Traditionally, post-job analysis has been limited to high-level pack evaluation and failure investigation but has a much wider range of applications in the confirmation of success, better understanding of downhole mechanisms and validation of simulation models. Downhole data analysis techniques can be used to isolate sections of the flow path and develop a more detailed understanding of each stage of the treatment from running in the hole (RIH) to pulling out of the hole (POOH).\u0000 Detailed post-job evaluation is often skipped due to the significant effort involved in data handling as well as the lack of a defined workflow and an integrated software tool. This paper provides an overview of the evaluation and calibration of surface and downhole data along with the steps, workflow and tools required to process the data in the easiest and most efficient manner, enabling faster, more detailed and more accurate analysis of operations.\u0000 Various case studies are used to demonstrate how post-job evaluation using downhole gauges can be used to efficiently analyse the various stages of the operation including wellbore displacements, reverse and circulating step rate tests and gravel packing operations. A variety of important phenomena are identified and quantified, such as friction pressures, packing mechanisms, fluid displacements, screen plugging and roping, which may otherwise be missed. The paper further illustrates how the defined workflow can maximize the likelihood of success by using post-job evaluation results to better identify and minimize risks during pre-job design stages while reducing the need for excessive safety factors within the operational window.\u0000 The analysis workflows introduced here will maximize the value of downhole gauge data and serve as a reference to practicing completion engineers in the efficient processing, analysis and interpretation of post-job data. It can be used to revisit and better understand historical sand control treatments, and continuously improve future treatments.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132804295","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Analytical and Numerical Solutions for Interpretation of Chemical Compaction in Chalk","authors":"P. Andersen, D. Berawala","doi":"10.2118/192018-MS","DOIUrl":"https://doi.org/10.2118/192018-MS","url":null,"abstract":"\u0000 Chemically reactive flow is of significant importance for EOR due to possible wettability alteration (low salinity and smart water brines), scaling and chemically enhanced compaction, which all can affect hydrocarbon transportation. In particular, chalks (Ekofisk, Valhall) are highly sensitive to the composition of the injected brine (typically modified seawater) as demonstrated on lab and field scale. We present numerical and analytical solutions to interpret the link between geochemical alterations and creep compaction in chalk cores.\u0000 A 1D core scale model is proposed for interpreting geochemical compaction during reactive brine injection into chalk cores loaded uniaxially in creep state (compaction under constant applied effective stresses). An analytical solution is derived to describe the steady state ion and dissolution rate distributions. An analytical model for creep compaction is proposed based on the applied affective stress and the rocks ability to carry that stress as function of porosity. The two models are coupled as follows: The compaction rate is assumed enhanced by the dissolution rate. Further, the solid volume changes by mineral dissolution and precipitation, also affecting the compaction rate. Brine-dependent and non-uniform compaction is therefore built into the model via the dissolution rate distribution.\u0000 The model is validated against data from ~ 25 core samples where simple Mg-Ca-Na-Cl brines were injected at Ekofisk reservoir conditions (130 °C), in particular experimentally measured effluent concentrations, distributions in mineralogy after flooding and creep compaction behavior. The model captures the effect of varying key parameters such as brine composition, injection rate and initial porosity and can predict ionic and mineralogical profiles along the core, axial and radial deformation profiles locally and with time. This model is a highly useful tool for interpreting experimental data, predicting in-situ mineralogical distributions where measurements have not been made, and for predicting compaction behavior at changes in brine composition, injection rate or effective stress.\u0000 The model is intended for giving a prediction of qualitative and quantitative trends during flooding-compaction tests in chalks. The model and its methodology are translatable to other systems but is validated for lab measurements on chalk samples. Current modeling approaches do not consider the complex interplay between brine and rock compositions, reaction and compaction. This work aims to contribute to the current understanding of this topic.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131459618","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Maximising Value of an Appraisal DST: Recording a 10,000 Hour Build-up in an Abandoned Well Using Wireless Downhole Gauges","authors":"S. Walters, G. Ward, M. Cullingford","doi":"10.2118/192053-MS","DOIUrl":"https://doi.org/10.2118/192053-MS","url":null,"abstract":"\u0000 Reservoir connectivity over production timescales is a key uncertainty impacting estimated ultimate recover (EUR) per well, and ultimately the economics of a development, but is difficult to address without production data (particularly where the reservoir is poorly defined by seismic). While appraisal well tests can be designed to help predict the performance of future development wells, high rig costs in deepwater means the test duration is often insufficient to investigate the volume that would be accessed under production conditions. Recoverable resources from a recent deepwater gas discovery were dependent on demonstrating significant reservoir connectivity and net reservoir volume; however, this was complicated by a lower delta plain interval that was dominated by sub-seismic reservoir elements.\u0000 This paper describes the acquisition and interpretation of long-term pressure build-up data in a plugged and abandoned deepwater appraisal well. To accomplish the test objectives at an acceptable cost, we turned to a novel combination of well testing, wireless gauge technology and material balance techniques to allow the collection and interpretation of reservoir pressure data over a planned period of 6 to 15 months following the well test. The final build-up duration was 428 days (14 months).\u0000 Three interpretation methods of increasing complexity were used to provide insights into the reservoir. Firstly, material balance was used to produce an estimate of the minimum connected reservoir volume. The advantage of material balance is that it requires very few input assumptions and produces a high confidence result. Secondly, we used analytical models in commercial pressure transient analysis software to investigate near wellbore properties and distances to boundaries. Finally, we used finite difference simulation models to investigate reservoir properties and heterogeneity throughout the entire tested volume. With increasing model complexity came additional insights into the reservoir properties and architecture but reduced solution uniqueness.\u0000 A key complication for the interpretation of the recorded pressure data was the potential for gauge drift to occur – this was incorporated into the uncertainty range used in all three interpretation methods. The observed relative performance for the various gauges used during the well test is also reported in this paper.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"54 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126438024","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Smart Software System for Flow Assurance Management","authors":"Akanksha Jain, N. Patel, P. Hammonds, S. Pandey","doi":"10.2118/191951-MS","DOIUrl":"https://doi.org/10.2118/191951-MS","url":null,"abstract":"\u0000 Access to real time production and injection data available on a desktop greatly enhances a production optimization engineer's efficiency. This paper describes a smart management system utilized for retrieving and evaluating all flow assurance related data for more than 700 wells. These wells are located in both onshore & offshore fields operated by Cairn Oil & Gas, a vertical of Vedanta Limited. The paper discusses system architecture, interface details, system design, functionality, visualization, application and benefits of the system.\u0000 To avoid unnecessary replication of data entry or retrieval, the system interfaces with other software systems. The software is also capable of direct hardware interfacing for data retrieval and system control. Currently the system connects to a range of software that includes Digital Oilfield Management System, Well Intervention Information System, and Laboratory Information Management System. The smart system is utilized as a single point for managing/ monitoring data from all such interfaces. Data may also be entered manually using standard templates, csv files, attachments (videos, photographs, documents, log files etc.) and spreadsheets.\u0000 The system is fully web-enabled, real time and is used for performance monitoring of all flow assurance and well stimulation related data. The data includes stimulation treatment design, scale inhibitor squeeze performance, scale monitoring and prediction, water chemistry, chemical performance monitoring, corrosion prediction and monitoring etc. The input data is converted into information within the system by a powerful calculation/logic engine; enabling users to analyze issues/problems more efficiently and provide faster resolution. The system includes automatic alarms, emails, reporting, future projections, etc.\u0000 Automated cumulative cost performance plots (Scorpion plots) are also inbuilt in the system and are used to evaluate cost-benefit of individual chemical treatments. These analyses enable well productivity to be improved and ineffectual operations to be abandoned. Examples of well stimulation assessment are included, which illustrate the value of analytics on performance improvement. The smart system covers raw data to dashboard information and setting realistic KPIs for future well interventions with respect to remediation and inhibition. Other examples include both in-built prediction tools (hydrogen sulphide phase equilibria) and linked software such as predicting scale deposition, squeeze lifetime modelling and corrosion rate prediction. Although running with live data retrieval, the system start up included upload of all historical data, thus ensuring utility from the outset.\u0000 This software also has new modules added which enables the analysis of sporadic operation data (e.g. stimulation pumping analysis); cumulative cost production analysis and fracturing operations. This smart system will allow an engineer to make better informed decisions based on a c","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131766245","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of Managed Pressure Drilling on a Semisubmersible Tender-Assisted Rig to Address Drilling Challenges in HPHT Gas Condensate Wells, Offshore Vietnam","authors":"Harpreet Singh, B. Quoc, T. Yong, Do Van Khanh, Nguyen Xuan Cuong, Hoang Thanh Tung, Truong Hoai Nam, Ngo Huu Hai, D. A. Tuan, Trinh Ngoc Quoc Bao, T. N. Hung, Nguyen Pham Huy Cuong","doi":"10.2118/191927-MS","DOIUrl":"https://doi.org/10.2118/191927-MS","url":null,"abstract":"\u0000 High-pressure, high-temperature (HP/HT) environments often present kick and losses scenarios. Bien Dong POC Well-1 serves as an example of such scenarios with a very narrow-pressure operating window. Operational pressure challenges prohibited achieving the objectives.\u0000 While drilling the Bien Dong Well-1, the well encountered ballooning issues, high pore pressures, and a narrow window. As part of remedial actions when drilling Bien Dong Well-2 & Well-3, the Bien Dong POC drilling team decided to deploy MPD technology with constant bottomhole pressure and early kick-loss detection capabilities.\u0000 By applying MPD techniques, the team drilled the 12-1/4-in. hole section with the lowest possible mud weight to accommodate the narrow drilling window. Drilling the well sections to total depth (TD) took only 10 days in Well-2 and 14 days in Well-3. MPD also allowed stripping out of the hole with surface backpressure (SBP) instead of pumping out of the hole to minimize swab once in shoe, which reduced trips for considerable rig-time savings.\u0000 The wells were drilled using MPD technology on a semisubmersible tender-assisted rig. A comprehensive rig survey was conducted during the planning phase of rig construction. The survey outlined the permanent installation of the MPD system, including an automated MPD choke manifold and docking-station rotating control device (RCD). The MPD equipment was integrated into the rig on a flexible plug-and-play basis to enable easy rig up and rig down. The integration also enabled moving the equipment between wells when the rig skids and during the MPD operation. The success of MPD operations came through cooperation with team members, experience from lessons learned, and excellence in rig crew performance on well after well.\u0000 This paper will discuss how MPD technology led to campaign improvements and cost savings throughout Bien Dong Well-2 and Well-3.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"42 19","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113974452","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Case Study Applied Machine Learning to Optimise PCP Completion Design in a CBM Field","authors":"Charles Prosper, D. West","doi":"10.2118/192002-MS","DOIUrl":"https://doi.org/10.2118/192002-MS","url":null,"abstract":"\u0000 The key objective of multiple Coal Bed Methane (CBM) development operations is to determine cost effective methods to allow sustainable economic production and maximum reserves recovery. The cost of workovers as well as the associated deferred production may overwhelm the economic viability of the field. The primary reason for workovers is progressive cavity pump (PCP) system failures.\u0000 Here, we demonstrate the use of a machine learning framework that can be used to customise each workover configuration such that it optimises PCP run-life, respecting the well's heterogeneity and age. The framework can be generalised into three major parts: 1) converting the dynamic production data into a stationary surrogate model for the well; 2) the use of Gaussian process regression to create a function that estimates runlife; 3) an optimiser that will search the functional space to recommend the best completion design.\u0000 A telemetry and completion dataset for PCP run-lives from years 2014-2018 was obtained across the Surat and Bowen basins. After filtering data for completeness, 1499 PCPs remained in the cohort, of which, 895 failed during the observation period. A small portion of the original data was used as a test set.\u0000 Our work suggests that PCP run-life can be extended by taking a multivariate statistical approach to provide recommendations for customised completions and production strings per well that respect the wells’ geology and production history and thereby improve life of field economics.","PeriodicalId":413759,"journal":{"name":"Day 2 Wed, October 24, 2018","volume":"108 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124820506","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}