Day 1 Mon, September 30, 2019最新文献

{"title":"Re-Perforating Formerly Inaccessible Well Areas Beneath Completion Collapse and Axially Displaced Tubulars","authors":"Troup Duncan, Kristiansen Roy, Maouche Maxime","doi":"10.2118/196151-ms","DOIUrl":"https://doi.org/10.2118/196151-ms","url":null,"abstract":"\u0000 In several producing fields throughout the Norwegian continental shelf, operators are facing aging wells with heavily deformed completions that are producing below their potential. In order to find a technical solution to improve production that can be operated through completion deformations, Archer, Archer has pursued a full technical study of existing collapse geometry, axial pipe displacement and reproduced them in full scale 3D models in order to test a newly engineered slim and highly flexible perforating system designed to be conveyed by carbon composite rod with embedded electrical cable.\u0000 In March 2018, work began in parallel on two linked projects. We needed first to understand the different profiles and geometries of an inaccessible deformed tubular, in order to reproduce and model the axial displacement on scale. In parallel with the deformation modelling, we needed to engineer with our perforating system manufacturer an interchangeable and flexible perforating system capable of passing through the 3D model deformations.\u0000 A complete study of downhole recorded well data from deformed areas was performed to catalogue the different possible shapes and internal diameter reduction of tubing and liner under axial compression. A 3D modelled transparent plastic tubular system has been engineered in order to reproduce the exact downhole dimensions and conditions of known deformed areas. The modelled deformations needed to be robust and long enough to support real downhole tools and fully transparent so we could understand the different toolstring’s behaviorsbehaviours depending on the Bottom Hole Assembly (BHA) set up and shape of the deformation. The deformation testing system has been created as a light weight interchangeable tubular system designed to interlock quickly and easily in various combinations.\u0000 In the meantime in the parallel twin project, the initial task was to review the current product portfolio of slim through tubing equipment. The completion with heavy wall liners, intended to minimize the deformation caused by reservoir formation movements, challenged the charges selection that could be fitted into slim perforation systems. Due to the minimum hole size requirement, the gun system was also designed to self-orient to the low side of the casing. The drafting team analyzedanalysed the internal gun system and added a weighted row to assist with gun orientation. The final system to be tested in the modelled deformation is composed of interchangeable swivels, knuckle joints, rollers, and single or multiple shot slim and short guns incorporated with addressable switches.\u0000 Over 30 different well deformation shapes have been recreated in order to test and select the best performing flexible perforating system combination, leading to more than 200 documented results. The flexibility and reduced Outer Diameter (OD) of both downhole system and composite carbon rod allows to pass successfully through several heavily deformed tubulars,","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127508173","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":"Effect of Asphaltene Precipitation and Deposition on Miscible Viscous Fingering in Porous Media — High-Resolution Nonlinear Numerical Simulations","authors":"N. Sabet, M. Mohammadi, Ali Zirahi, Mohsen Zirrahi, H. Hassanzadeh, J. Abedi","doi":"10.2118/196115-ms","DOIUrl":"https://doi.org/10.2118/196115-ms","url":null,"abstract":"\u0000 This work focuses on modeling the miscible viscous fingering in porous media accounting for asphaltene precipitation and deposition. The mass balance equations for solvent and asphaltene are defined, and the highly nonlinear system of equations is solved numerically through hybridization of compact finite difference and pseudo-spectral methods. We explain how asphaltene precipitation and the resulting formation damage influence the growth of viscous fingers.\u0000 To conduct our analysis, we use the experimental data for the amount of asphaltene precipitation at different solvent mass fractions and also oil viscosity at various asphaltene and solvent contents. This data is measured in our lab and is used as input for the nonlinear numerical simulations. For these simulations, the conventional finite difference schemes cannot be applied as they suffer from the excessive computational time and most importantly, numerical dispersion. Therefore, we employ hybrid techniques to benefit from the high accuracy of spectral methods and capture the nonlinear dynamics of fingerings on very fine grids.\u0000 Hydrocarbons such as light n-alkanes are widely used as diluents in the production and upgrading of heavy oils. The addition of a diluent to heavy oil or bitumen alters the chemical forces acting within the mixture, leading to the precipitation of asphaltenes. It is hypothesized that precipitation of asphaltene from oil changes the viscosity behavior of the mixture, influences the dynamics of viscous fingering, and therefore affects the oil recovery. Moreover, asphaltene deposition alters the porosity and permeability of the porous media and might modify the flow paths, leading to possible formation damage. Our results show that asphaltene precipitates are mostly accumulated in the contact interface between the solvent and oil. The major asphaltene deposition occurs along the growing fingers leading to permeability reductions up to 30% in the studied cases.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132414913","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":"Evaluation of Air Injection into Mature SAGD Chambers as a Follow Up/Wind-Down Strategy, Using a Novel Large Scale 3-D Physical Model","authors":"Ehsan Aminfar, B. Sequera-Dalton, Sudarshan Mehta, G. Moore, M. Ursenbach","doi":"10.2118/196049-ms","DOIUrl":"https://doi.org/10.2118/196049-ms","url":null,"abstract":"\u0000 The injection of air into mature steam chambers is a promising technology to reduce the steam-to-oil-ratios (SOR) in late stages of the Steam-Assisted-Gravity-Drainage (SAGD) recovery process in Athabasca oil sand reservoirs in Alberta, Canada. Air injection allows sustaining steam chamber pressures with reduced steam injection rates. The steam capacity that becomes available due to the replacement of steam with air in mature well-pairs or pads could serve new pads optimizing steam utilization and decreasing the overall environmental footprint of the project. A novel large scale three-dimensional (3-D) physical model was designed to evaluate the prospect of the \"hybrid\" air and steam injection technology in a SAGD configuration utilizing up to three well-pairs. This paper discusses the 3-D model design, commissioning, experimental procedure and main results of the first tests.\u0000 For each test, the 3-D model was packed with a low oil saturation core or lean zone, representing the reservoir portion swept by steam, and a high oil saturation core or rich zone representing the un-drained zone between two coalesced steam chambers. These zones were made with preserved native \"lean\" and \"rich\" cores from Athabasca reservoirs. Once the model was packed, it was placed inside a pressure jacket where it was pressurized to reservoir pressure. Steam was injected into the model to develop a representative steam chamber in the lean zone. Once steam conditions were attained in the lean zone, steam injection was switched to air injection. Temperatures distributed in the 3-D model as well as injection and production pressures and produced gas compositions were monitored constantly and recorded during the test. Produced liquid samples were regularly captured and stored for subsequent analysis. Post-processing analyses of produced fluids and residual extracted core material allowed for determination of clean-burned zones, material balance, upgrading of the produced bitumen samples and efficiency of the process.\u0000 High peak temperatures, gas compositions, clean-burned sand in post-test cores and significant oil production indicate the development of a high temperature combustion front in the 3-D experiments. The test results confirm the injection of air into mature SAGD chambers is a very promising method not only to reduce the cumulative steam-to-oil-ratios (CSOR) and to sustain the steam chamber pressures but also to increase oil production in SAGD late life.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"33 7-8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131876327","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":"Reservoir Characterization-Geostatistical Modeling of the Paleocene Zelten Carbonate Reservoir. Case study: Meghil Field, Sirte Basin, Libya","authors":"M. Masaud, W. Meddaugh","doi":"10.2118/195988-ms","DOIUrl":"https://doi.org/10.2118/195988-ms","url":null,"abstract":"\u0000 Geostatistical-based models provide a considerable improvement for predictive reliability of dynamic models and the following reservoir management decisions. This study focuses on geostatistical modeling the Paleocene Zelten Carbonate reservoir in the Meghil field. The field was discovered in 1959 and production operations began in 1961. Nineteen wells have been drilled to date. The structural framework consists of three slightly asymmetrical anticlinal structures trending NW-SE with steeper dip on the SW flanks. Each of the structures are separated by major normal faults. Seismic interpretation suggests that carbonate build-ups are most likely present on the three separate structures. Edge detection was used to clarify the structural geometries and the presence of additional minor faults. Pillar gridding technique was used to develop the structural framework including four major faults that are partially sealed based on analysis of the available DST and production test data. Stratigraphic analysis indicates a local presentation of dolomitic limestone in the northern portion of the main and the western structures caused considerable litho-facies variation that impacted the distribution of the petrophysical properties. Basic and advanced formation evaluation the net reservoir thickness of about 15 feet with an average porosity of 17% and average water saturation of 35%. Geostatistical-based applications that combine the spatial statistics (e.g. the semivariogram) and the available well and core data were used to populate the reservoir model with porosity, permeability, facies (lithology), net/gross, and water saturation. A conceptual facies model was also used to constrain the reservoir property distributions. Sequential Gaussian Simulation (SGS) was used to populate the model with porosity and water saturation and Sequential Indicator Simulation (SIS) was used to populate the facies model with permeability. The modeling parameters (e.g. semivariogram, correlation coefficients) were significantly constrained by the limited number of wells. Based on the limited number of wells available the semivariogram analysis resulted in a spherical semivariogram model with major axis range of 1435 meters for porosity and 1800 meters for water saturation. Minor axis ranges were about 50% of the major axis ranges. Given the limited well data, a significant effort was made to document the potential impact of the semivariogram parameters on the original hydrocarbon in place (OHIP) estimates and the lateral stratigraphic continuity of reservoir properties. The deterministic approach resulted in place volume estimates of 60 MMBBL and the stochastic approach provided an estimate of 45 MMBBL.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"2 2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113957353","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":"Evaluating Precision of Fluid/Casing Design for Annular Pressure Build-Up APB Application Using Machine-Learning Tools","authors":"S. Kulkarni, Aditya Vyas, H. Gupta","doi":"10.2118/196179-ms","DOIUrl":"https://doi.org/10.2118/196179-ms","url":null,"abstract":"\u0000 Annular Pressure Build-up (APB) is caused by heating of the trapped drilling fluids (during production) which may lead to burst/collapse of the casing or axial ballooning, especially in subsea HP/HT wells. The objective of present paper is to apply machine-learning tools to increase precision of the APB estimation, and thereby improve the fluid and casing design for APB mitigation in a given well.\u0000 The APB estimation methods in literature involve theoretical and computational tools that accommodate two separate effects: volumetric expansion (PVT response) of the annulus drilling fluids and circumferential expansion (and corresponding mechanical equilibrium) of the well casings. In the present work, machine-learning algorithms were used to accurately model ‘fluid density=f(T,P)’ based on the experimental PVT data of a given fluid at a range of (T, P) conditions. Sensitivity analysis was carried out to demonstrate improvement in precision of APB estimation (for different subsea well scenarios employing different fluids) using the machine-learning based models.\u0000 The study demonstrated that, in several subsea scenarios, a relatively small error in the experimental fluid PVT data itself can lead to significant variation of in APB estimation. The machine-learning based models for ‘density = f(T,P)’ for the fluids ensure that the cumulative error during the modeling process is minimized. The use of certain machine-learning based density models was shown to improve the precision of APB estimation by several hundreds of psi. This advantage of the machine-learning based density models was employed to improve the casing/fluid design for APB mitigation; the case was demonstrated for a subsea well scenario. Accordingly, the work may be used to mitigate the APB issue in the subsea HP/HT wells.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"49 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127927616","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":"Reviving a Mature, Watered-Out Fractured Carbonate Reservoir: An Integrated Approach to Design a Miscible EOR Scheme for the Bigoray Field in Alberta","authors":"J. Rivero, M. Faskhoodi, Herman Mukisa, W. Zaluski, H. Lahmar, D. Andjelković, Cindy Xu, C. Ibelegbu, Hanatu Kadir, W. Sawchuk, Warren Pearson, Raouf Ameuri, O. Gurpinar","doi":"10.2118/196156-ms","DOIUrl":"https://doi.org/10.2118/196156-ms","url":null,"abstract":"\u0000 The Bigoray area of the Pembina field in western Alberta consists of approximately 50 naturally fractured Nisku carbonate reefs. Production from the Bigoray Nisku D and E pools started in 1978, and shortly after, water injection was initiated to maintain reservoir pressure as a secondary drive mechanism. By 2013, the pools had reached high water cuts, making them uneconomical to produce. In 2017, a decision was made to reactivate the pools and initiate a solvent injection enhanced oil recovery (EOR) project feasibility assessment.\u0000 A multidisciplinary team was assembled to review and reinterpret all the geoscience data with modern methodologies to characterize the reservoirs and create new static model descriptions to be used in a dynamic model. Data from well logs, seismic, core measurements, and image logs were integrated into a comprehensive and consistent model that could be used with certainty as a prediction tool.\u0000 A history-matching process was carried out by creating different realizations of the static model to honor well-to-well connectivity and water movement within the pools. The history-matching process was performed while ensuring that the model updates were global in nature and consistent with the geological understanding of the reservoirs.\u0000 The history-matched model was used to optimize the location of new producers and injectors based on remaining oil saturations and reservoir structure. Optimization of the EOR scheme involved testing a matrix of scenarios to investigate the effect of injection rates and solvent volumes as well as production pressures and voidage ratios. Additionally, in an effort to improve displacement efficiency, a large number of simulation runs were devoted to test and establish the most efficient locations for the well perforations in both the new injectors and producers.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"44 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116905841","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":"Anisotropic Fault Leakage into Multiple Shallower Formations Connected to an Injection Zone","authors":"M. Mosaheb, M. Zeidouni","doi":"10.2118/196154-ms","DOIUrl":"https://doi.org/10.2118/196154-ms","url":null,"abstract":"\u0000 Faults can conduct fluids to shallower formations that may adversely affect groundwater resources and ultimately surface environment during geological storage of carbon dioxide. In this study, an analytical model is derived for a multilayer system that is intersected by a leaky fault. The fault-zone structure and anisotropic flow inside the fault zone are considered which are necessary for fault leakage characterization. The fault-zone structure includes damaged zones with high permeability and a core zone in between with low permeability. The diffusivity equations are written for the multilayer system as well as the fault zone and the system of equations is solved by Laplace and Fourier transforms. The solution is capable to investigate up-, across-, and along-fault fluid flow as well as pressure variations of the shallower formations. Using the pressure variations of the injection well, the vertical extension of fault leakage to shallower formations is evaluated.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"33 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115255488","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":"Bringing Uncertainty to the Forefront of Informed Decision Making in Oil and Gas Exploration and Development","authors":"P. Wanjau, R. Bloomfield, Jennifer R. Bauer, K. Rose","doi":"10.2118/196094-ms","DOIUrl":"https://doi.org/10.2118/196094-ms","url":null,"abstract":"\u0000 As data computing and big data driven analytics become more prevalent in a number of spatial industries, there is increasing need to quantify and communicate uncertainty with those data and resulting spatial analytical products. This has direct implication in oil & gas exploration and development where big data and data analytics continue to expand uses and applications of spatial and spatio-temporal data in the industry without providing for effective communication of spatial uncertainty. The result is that communications and inferences made using spatial data visuals lack crucial information about uncertainty and thus present a barrier to accurate and efficient decision making. With increasing cost awareness in oil & gas exploration and development, there is urgent need for methods and tools that help to objectively define and integrate uncertainty into business decisions.\u0000 To address this need, the Variable Grid Method (VGM) has been developed for simultaneous communication of both spatial patterns and trends and the uncertainty associated with data or their analyses. The VGM utilizes varying grid cell sizes to visually communicate and constrain the uncertainty, creating an integrated layer that can be used to visualize uncertainty associated with spatial, spatio-temporal data or data-driven products.\u0000 In this paper, we detail the VGM approach and demonstrate the utility of the VGM to intuitively quantify and provide cost-effective information about the relationship between uncertainty and spatial data. This allows trends of interest to be objectively investigated and target uncertainty criteria defined to drive optimal investment in improved subsurface definition. Examples are presented to show how the VGM can thus be used for efficient decision making in multiple applications including geological risk evaluation, as well as to optimize data acquisition in exploration and development.\u0000 Today, uncertainty, if it is provided at all, is generally communicated using multiple independent visuals, aggregated in final displays, or omitted altogether. The VGM provides a robust method for quantifying and representing uncertainty in spatial data analyses, offering key information about the analysis, but also associated risks, both of which are vital for making prudent business decisions in oil & gas exploration and development.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115686754","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":"Applying Decision Trees to Improve Decision Quality in Unconventional Resource Development","authors":"P. Miller, J. Gouveia","doi":"10.2118/195811-ms","DOIUrl":"https://doi.org/10.2118/195811-ms","url":null,"abstract":"\u0000 Decision trees have been used for many years in conventional oil and gas plays to help managers better understand risk and expected value for a project. Although industry has rapidly shifted over the past decade to developing unconventional resources, application of decision trees to these plays has lagged behind. When building decision trees for unconventional plays, it is often unclear to evaluators how to build the tree, namely, how to estimate the probability of meeting a given commercial threshold, as well as the production profiles and costs to use for each branch of the tree. This paper presents a workflow that can be used to build a decision tree for an unconventional play in the appraisal phase of development, given ranges of uncertainty in production profiles and drilling and completion costs. In applying this workflow, managers will better understand both the drivers of uncertainty in expected value and how they can influence it via appraisal program design and setting commercial thresholds. An example from a North American unconventional play is used as an example to illustrate the steps of the workflow.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114550099","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 Multizone Water Injection Downhole Flow Control Completions with Fibre-Optic Surveillance in Soft Sand Reservoirs","authors":"Dzu Nguyen, I. Macleod, D. Taylor, L. Murray, D. Zavyalov, D. Booth, N. Robertson, Robert Smith, Jonathon Joubran, Clifford Allen, Sharil Mohd Shafei","doi":"10.2118/196231-ms","DOIUrl":"https://doi.org/10.2118/196231-ms","url":null,"abstract":"\u0000 The multiple zone water injection project (MZWIP) was initiated to deliver the following key objectives: deliver zonal injection with conformance control and reliable sand management across the major layered sands of the Balakhany unconsolidated reservoirs in the BP operated Azeri-Chirag-Gunashli (ACG) fields in Azerbaijan sector of the Caspian Sea.\u0000 Three years after MZWIP implementation, six wells with a total of 14 zones are injecting at required rates with zonal rate live-reporting. To achieve this multizone injection facility, the requirement for a standard ACG sand-control injector design was discounted and a non-standard sand management control technique developed using a cased & perforated (C&P) and downhole flow-control system (DHFC). During this program, BP ACG has successfully installed the world's first 10kpsi three-zone inline variable-choke DHFC wells with distributed temperature sensors (DTS) across all target injection zones.\u0000 The choking DHFC provides flexibility in operations and delivers the right rates to the right zones. The DTS provides conformance surveillance, fracture assessment, caprock integrity and sand ingress monitoring capability. A customized topside logic control system provides an automatic shutin of interval control valves (ICVs) during planned or unplanned shutins to stop crossflow and sand ingress and is the primary method of effectively managing sanded annuli.\u0000 The development of this MZWI solution has significantly changed the Balakhany development plan and has been quickly expanded across five ACG platforms. Accessing 2nd and 3rd zones in the same wellbore, this C&P DHFC well design is accelerating major oil volumes and will significantly reduce future development costs, maximizing wellbore utility in a slot-constrained platform.","PeriodicalId":325107,"journal":{"name":"Day 1 Mon, September 30, 2019","volume":"172 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-09-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124875963","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}