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Picture for Application of Encapsulated Scale Inhibitors - Understanding the Field Success Factors
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51317--9527-Application of Encapsulated Scale Inhibitors - Understanding the Field Success Factors

Product Number: 51317--9527-SG
ISBN: 9527 2017 CP
Author: Mike Jackson
Publication Date: 2017
$20.00

This product slowly dissolves for long term scale/corrosion protection. This paper describes the chemical management system that reviewed: statistical interpretation of the results, laboratory methodologies, software simulations to calculate (a) the amount of encapsulated materials (b) frequency of treatment, (c) the economic analysis.

 
Picture for Chelating Agents for Iron Sulfide Scale Removal at 300°F (149°C)
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Chelating Agents for Iron Sulfide Scale Removal at 300°F (149°C)

Product Number: 51320-14859-SG
Author: Raja Ramanathan , Hisham A. Nasr-El-Din
Publication Date: 2020
$20.00

Iron sulfide scales create well deliverability and integrity problems such as reduced production rates and damage to well tubulars. Chelating agents have scarcely been studied for iron-sulfide dissolution. This paper evaluates EDTA, DTPA, and HEDTA for its iron sulfide (FeS) dissolution capacity and kinetics at 300°F (149°C). 

A comparative study of the chelating agents with a low pH (3-5), moderate pH (5-9), and high pH (9-14) determined the optimum pH for the scale treatment. These tests were conducted in glass bottles and a high-temperature autoclave apparatus under anoxic conditions. Results show that the iron-sulfide dissolution increases tremendously at 300°F (149°C) when using chelating agents with a pH>5. At 300°F (149°C), the bond strength is reduced, allowing the chelating agents to remove the metal ion from the solid surface. The ranking of the chelating agents in terms of iron-sulfide scale dissolution capacity and effectiveness was DTPA>EDTA>HEDTA at all pH conditions. The role of chelating agents in iron sulfide dissolution at 300°F (149°C) has not been thoroughly investigated. There is no study that reports the optimum treatment time at that temperature. This paper investigates chelating agents and provides the optimum dissolver composition and treatment time for field operations at high temperature conditions. 
Picture for Deposition And Corrosion Mitigation Using Surface Treatments
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Deposition And Corrosion Mitigation Using Surface Treatments

Product Number: 51321-16729-SG
Author: Erika Brown; Marshall Pickerts; Carolyn Koh; Jose Delgado; Vinod Veedu
Publication Date: 2021
$20.00
Picture for Development Of A Tool To Track The Fraction Of Injected Water In Produced Water Streams
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Development Of A Tool To Track The Fraction Of Injected Water In Produced Water Streams

Product Number: 51323-19130-SG
Author: Thibaut V. J. Charpentier, Rose Lehman, Andre Leontieff
Publication Date: 2023
$20.00

Waterflooding is a common secondary recovery technique where injection water (IW) is used to maintain reservoir pressure and improve oil recovery. During such operations, the mobile hydrocarbon phase is displaced along with formation water (FW) toward producing wells. The resulting produced water stream is a blend of FW and IW; these waters can be incompatible resulting in dissolved ions to precipitate out of solution as mineral scale.
Picture for Development of an F22 Metal Compatible Scale Inhibitor for Subsea Application
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Development of an F22 Metal Compatible Scale Inhibitor for Subsea Application

Product Number: 51323-19069-SG
Author: Chunfang Fan, Wei Zhang, Tiffany Nguyen, Jason Moses, Alexander Nelson, David Orta
Publication Date: 2023
$20.00

Mineral scale deposition is one of the major flow assurance issues for the oil and gas industry. When an oil or gas well produces water, there is the possibility that scale could form either by the mixing of incompatible waters forming oversaturated brine or by direct precipitation of the water that occurs naturally in reservoirs due to the changes in pressure, temperature, or pH. Scale inhibitors are commonly used to prevent mineral scale formation during oil and gas production and mitigate this flow assurance issue.
Picture for Development of Iron Sulfide Scale Inhibitor For Ultra-Tight Sandstone
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Development of Iron Sulfide Scale Inhibitor For Ultra-Tight Sandstone

Product Number: 51322-17896-SG
Author: Cyril Okocha, Tao Chen, Alex Thornton, Qiwei Wang
Publication Date: 2022
$20.00

Oilfield sulfide scale formation is peculiar to sour production scenarios, and for many oil and gas fields the issue of iron sulfide scale management downhole presents a major challenge. Historically iron sulfide scaling downwell have featured ‘reactive’ chemical dissolver interventions to recover well production once sulfide scale has deposited, and operators have published extensively on their experiences i.e. coiled tubing deployed dissolver technologies used in well clean-out treatments (Green, et.al. 2014, Wang et.al. 2017, Wang et.al. 2018, Buali et. al 2014).
Picture for Flow Assurance Testing With Re-Livened Oil – A Cost-Effective Analogue For Live Oil
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Flow Assurance Testing With Re-Livened Oil – A Cost-Effective Analogue For Live Oil

Product Number: 51322-17822-SG
Author: Andrew Robert Farrell, Dario Marcello Frigo, Gordon Michael Graham
Publication Date: 2022
$20.00

Precipitation and deposition of wax or asphaltenes is a commonly encountered issue in the oilfield, causing flow restrictions, compromising the integrity and performance of equipment (some safety critical), limiting access during well interventions, causing “fill” in vessels, stabilizing emulsions and sometimes enhancing corrosion due to under-deposit corrosion and increased biofouling. Developing an effective management strategy that minimizes the total cost associated with these threats requires reliable prediction of whether they will occur, their severity and their location within the production system. Such prediction typically combines the use of compositional data and phase behaviour (typically referred to as “PVT data) with Equation of State (EoS) modelling plus the experimental measurement of key parameters specific to each issue.
Picture for Pipeline Corrosion Management against Dynamic Production towards the Extended Life
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Pipeline Corrosion Management against Dynamic Production towards the Extended Life

Product Number: 51324-20670-SG
Author: Farih Mitraningsih; Aji Samiaji; Rudi Rinaldi; Muhammad Riduan Adhael
Publication Date: 2024
$40.00
A comprehensive corrosion assessment has been done to ensure the integrity of 24 inch outside diameter (OD) and 70 km length of transmission pipeline against production figure changes during and beyond of the initial design life. By design, the pipeline was intended to transport the wet gas for 20years design life with medium level of top of line and bottom of line corrosion likelihood. During operation, the pipeline was operated to sustain gas rate more than the designed capacity. Which commonly known as de-bottlenecking. In consequence, the corrosion likelihood increased as obtained from the inspection result. When the initial design life is almost over, the new reserves combining oil and wet gas is found thus the life extension assessment shall be accommodated. This paper summarizes the engineering study methodology and the results, thus the pipeline integrity able to synchronize the fit for purpose and production operation excellence.
Picture for Systematic Risk Evaluation of Calcium Sulfate Formation in Production System
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Systematic Risk Evaluation of Calcium Sulfate Formation in Production System

Product Number: 51323-19511-SG
Author: Tao Chen, Qiwei Wang, Faisal Alrasheed, Norah Aljeaban
Publication Date: 2023
$20.00

Scale formation is one of the flow assurance problems encountered in the oil and gas industry. It can deposit from reservoir, downhole tubing to topside facilities. Once formed, it could have a significant impact on production, including tubing and valve blockage, interference of well intervention, and even well abundance.

Calcium sulfate is one of the common scales formed in the oilfields.
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