scholarly journals Protocol for sand control screen design of production wells for clayey silt hydrate reservoirs: A case study

2020 ◽  
Vol 8 (5) ◽  
pp. 1438-1449 ◽  
Author(s):  
Yanlong Li ◽  
Fulong Ning ◽  
Nengyou Wu ◽  
Qiang Chen ◽  
Alireza Nouri ◽  
...  
Keyword(s):  
Screen Design ◽  
Sand Control ◽  
Clayey Silt ◽  
Production Wells ◽  
Hydrate Reservoirs

From Wellbore Breakout to Sand Production Prediction: An Integrated Sand Control Completion Design Methodology and Case Study

2021 ◽  
Author(s):  
Caleb DeValve ◽  
Gilbert Kao ◽  
Stephen Morgan ◽  
Shawn Wu
Keyword(s):  
Particle Size ◽  
Sand Particle ◽  
Well Performance ◽  
Sand Production ◽  
Natural Sand ◽  
Reservoir Development ◽  
Sand Control ◽  
Production Wells ◽  
Sandstone Reservoir

Abstract Controlling downhole sand production is a well-known and often-studied issue within the oil and gas industry. The methods employed for sand management, and their ultimate cost, is greatly impacted by the amount of sand produced by the well. This paper presents an innovative, physics-based approach to predict sand production for various reservoir and completion types, explored through a case study of recent production wells in a sandstone reservoir development. Sand control may be executed through a variety of methods, for example at the reservoir-completion interface using a sand control completion, at topside facilities through sand monitoring / de-sanding equipment, or by using well operational limits to avoid downhole sand failure. Although different strategies exist for effective sand management, some capability to estimate sand production is needed to design a holistic sand management strategy. This paper presents a physics-based approach to predicting sand production on a well-by-well basis to inform the overall sand management design. The workflow integrates (1) geomechanical estimate of wellbore breakout and volume of failed sand downhole, (2) log-based prediction of the sand particle size variation along the well path, (3) modeling of sand filtration based on experimental and analytical methods for specific completion options (e.g. Open Hole Gravel Pack [OHGP] or Stand-Alone Screen [SAS]), and (4) a natural sand pack permeability prediction for SAS completions and associated well performance analysis. This paper describes the methods used in this work in more detail as well as the application to five wells in a recent sandstone reservoir development. The workflow can be described as follows: First, log-based predictions for geomechanical properties and sand Particle Size Distributions (PSDs) were generated for specific wellpaths, and the volume of failed reservoir sand and PSD characteristics were predicted along the entire wellbore length. Next, this analysis was combined with a novel filtration model to determine sand retention and production, specific to various completion types. Additionally, for a SAS completion, the PSD and volume of retained sand in the annulus was computed as the wellbore experience borehole breakout, combined with an analytical model to calculate the natural sand pack permeability and well performance. This workflow was initially applied to study five development well producers, and the results influenced a mixed design of OHGP and SAS completions for individual wells. Sand production was measured during recent well startup to validate the workflow, with excellent agreement observed between measured field data and the physics-based predictions. This innovative, physics-based approach and the associated case study demonstrate a significant advancement in the area of sand production prediction from hydrocarbon production wells. The current workflow is able to deliver improved sand prediction capabilities over rules of thumb or analog field performance, which can be used to better inform overall sand management strategies and associated business value.

Sand Free Production Success Through Proven Technology Enabler from An Untapped Heterogeneous Reservoir Zone Utilizing Gravel Pack Replacement Methodology

2020 ◽  
Author(s):  
Y. Anggoro
Keyword(s):  
Oil And Gas ◽  
Erosion Resistance ◽  
Cost Effective ◽  
High Rate ◽  
Screen Design ◽  
Sand Control ◽  
Rules Of Thumb ◽  
Production Success ◽  
Control Technologies ◽  
Gravel Pack

The Belida field is an offshore field located in Block B of Indonesia’s South Natuna Sea. This field was discovered in 1989. Both oil and gas bearing reservoirs are present in the Belida field in the Miocene Arang, Udang and Intra Barat Formations. Within the middle Arang Formation, there are three gas pay zones informally referred to as Beta, Gamma and Delta. These sand zones are thin pay zones which need to be carefully planned and economically exploited. Due to the nature of the reservoir, sand production is a challenge and requires downhole sand control. A key challenge for sand control equipment in this application is erosion resistance without inhibiting productivity as high gas rates and associated high flow velocity is expected from the zones, which is known to have caused sand control failure. To help achieve a cost-effective and easily planned deployment solution to produce hydrocarbons, a rigless deployment is the preferred method to deploy downhole sand control. PSD analysis from the reservoir zone suggested from ‘Industry Rules of Thumb’ a conventional gravel pack deployment as a means of downhole sand control. However, based on review of newer globally proven sand control technologies since adoption of these ‘Industry Rules of Thumb’, a cost-effective solution could be considered and implemented utilizing Ceramic Sand Screen technology. This paper will discuss the successful application at Block B, Natuna Sea using Ceramic Sand Screens as a rigless intervention solution addressing the erosion / hot spotting challenges in these high rate production zones. The erosion resistance of the Ceramic Sand Screen design allows a deployment methodology directly adjacent to the perforated interval to resist against premature loss of sand control. The robust ceramic screen design gave the flexibility required to develop a cost-effective lower completion deployment methodology both from a challenging make up in the well due to a restrictive lubricator length to the tractor conveyancing in the well to land out at the desired set depth covering the producing zone. The paper will overview the success of multi-service and product supply co-operation adopting technology enablers to challenge ‘Industry Rules of Thumb’ replaced by rigless reasoning as a standard well intervention downhole sand control solution where Medco E&P Natuna Ltd. (Medco E&P) faces sand control challenges in their high deviation, sidetracked well stock. The paper draws final attention to the hydrocarbon performance gain resulting due to the ability for choke free production to allow drawing down the well at higher rates than initially expected from this zone.

Introducing the Application of Hybrid Gas and Sand Control in Sucker Rod Pump (SRP) Case Study Old Rimau Mature Field South Sumatera

2021 ◽  
Author(s):  
P. R. Safiraldi
Keyword(s):  
New Technology ◽  
Middle Section ◽  
Hybrid Device ◽  
Sand Control ◽  
Sucker Rod ◽  
Sucker Rod Pump ◽  
Gas Separator ◽  
Mature Field ◽  
Sandstone Reservoir

Objective/Scope: Challenges of sucker rod pumping operation in high gas and solid production;The implementation of integrated down-hole gas and solid separation in one device. Method procedure/processes: Old Rimau Fields in South Sumatera produce oil from sandstone reservoir with GOR above 800 scf/stb and solid production resulted from fracturing proppant flow back. Due to these conditions, some problems such as gas lock or interference, pump leakage, and rod parted were discovered which resulting in low SRP run life. The installation of sand screen and gas anchor has been implemented to encounter this issue. However, this initiative still ineffective due to limited conditions. If the sand screen was installed to control the sand, then the gas anchor to control the gas could not be installed and vice versa.Results, observations, conclusions: Integrated solid and gas handling called "hybrid" device has been introduced. The device is connected directly at the bottom of down-hole pump consist of three section, the upper section for intake and gas separator, the middle section for gas and solid separator, and lower one for solid container. The first utilization was conducted in three SRP wells, which are KG-09, LKP-21, and KG-10. Previously, these wells were shut-in due to down-hole problem. After installing the device while well service, the SRP run normally to produce the oil. The increasing of pump load performance was also obtained, indicated by the dyna card. At this time, the SRP is still running and run life is still under surveillance. This paper will explain the new technology end-to-end implementation of the integrated down-hole sand and gas control in one device for Sucker Rod Pump (SRP) system.

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