Enhanced transport of novel crystalline calcium-phosphonate scale inhibitor nanomaterials and their long term flow back performance in laboratory squeeze simulation tests

RSC Advances ◽  
2016 ◽  
Vol 6 (7) ◽  
pp. 5259-5269 ◽  
Author(s):  
Ping Zhang ◽  
Amy T. Kan ◽  
Mason B. Tomson
Keyword(s):  
Scale Inhibitor ◽  
Mineral Scale ◽  
Scale Control

Prepared crystalline Si–Ca–DTPMP scale inhibitor nanomaterials with enhanced transportability and extended squeeze lifetime potentially for oilfield mineral scale control.

Synthesis and laboratory testing of a novel calcium-phosphonate reverse micelle nanofluid for oilfield mineral scale control

RSC Advances ◽  
2016 ◽  
Vol 6 (46) ◽  
pp. 39883-39895 ◽  
Author(s):  
Ping Zhang ◽  
Dong Shen ◽  
Amy T. Kan ◽  
Mason B. Tomson
Keyword(s):  
Reverse Micelle ◽  
Laboratory Testing ◽  
Scale Inhibitor ◽  
Mineral Scale ◽  
Water Cut ◽  
Scale Control

Developed calcium-phosphonate scale inhibitor reverse micelle nanomaterial for oilfield mineral scale control in low water cut or water sensitive wells.

Scale Control for Long Term Well and Facility Preservation

2021 ◽  
Author(s):  
Chao Yan ◽  
Wei Wang ◽  
Wei Wei
Keyword(s):  
Oil And Gas ◽  
Saturation Index ◽  
Time Frame ◽  
Scale Inhibitor ◽  
Rock Interaction ◽  
Water Composition ◽  
Protection Time ◽  
Strontium Sulfate ◽  
Scale Control

Abstract Oilfield scale and corrosion at oil and gas wells and topside facilities are well known problems. There are many studies towards the control and mitigation of scaling risk during production. However, there has been limited research conducted to investigate the effectiveness of scale control approaches for the preservation of wells and facility during a potential long term shut-in period, which could last more than 6 months. Due to low oil price and harsh economic environment, the need to shut-in wells and facilities can become necessary for operations. Understanding of scale control for a long term period is important to ensure both subsurface and surface production integrity during the shut-in period. The right strategy and treatment approaches in scale management will reduce reservoir and facility damage as well as the resulting cost for mitigation. In this paper, we will review and assess the scale risk for different scenarios for operation shut-in periods and utilize laboratory study to improve the understanding of long-term impact and identify appropriate mitigation strategy. Simulated brine compositions from both conventional and unconventional fields are tested. Commercially available scale inhibitors are used for testing. Various conditions including temperature (131-171 °F), saturation index (1.28-1.73), pH (7.04-8.03) and ratio of scaling ions are evaluated. The tested inhibitor dosage range was 0-300 mg/L. Inhibitor-brine incompatibility was also investigated. Sulfate and carbonate scales such as barium sulfate, strontium sulfate and calcium carbonate are studied as example. This paper will provide an important guidance for the management of well shut- in scenarios for the industry, for both conventional and unconventional fields. Performance of two scale inhibitors for same water composition are demonstrated. The efficiency of scale inhibitor #2 is lower than that of inhibitor #1. A linear correlation is observed for long term scale inhibitor performance in this case. Protection time is thus predicted from data collected from the first 8-week experiments. The predicted protection time at 250 mg/L of inhibitor A and B is 100 weeks and 16 weeks respectively. The actual protection time will be compared to the predicted value. The inhibitor-rock interaction has also been preliminarily studied. The effects of inhibitor adsorption onto formation rock should be considered for chemical treatment design and performance/dosage optimization. This study provides novel information of scale control in a much longer time frame (up to 6 months). Various parameters may have effects on their long term control. Results will benefit the chemical selection and evaluation for long term well shut-in scenario. In addition, brine-inhibitor compatibility is evaluated simultaneously.

Functional scale inhibitor nanoparticle capsule delivery vehicles for oilfield mineral scale control

RSC Advances ◽  
2016 ◽  
Vol 6 (49) ◽  
pp. 43016-43027 ◽  
Author(s):  
Ping Zhang ◽  
Gedeng Ruan ◽  
Amy T. Kan ◽  
Mason B. Tomson
Keyword(s):  
Building Blocks ◽  
Scale Inhibitor ◽  
Functional Scale ◽  
Polymer Nanoparticle ◽  
Polymer Aggregates ◽  
Delivery Vehicles ◽  
Mineral Scale ◽  
Scale Control

This study synthesized phosphonate–polymer nanoparticle capsules using SiO2 nanoparticles as the building blocks and polymer aggregates as the template for the purpose of oilfield mineral scale control.

Phosphino-polycarboxylic acid modified inhibitor nanomaterial for oilfield scale control: transport and inhibitor return in formation media

RSC Advances ◽  
2016 ◽  
Vol 6 (64) ◽  
pp. 59195-59205 ◽  
Author(s):  
Ping Zhang ◽  
Dong Shen ◽  
Amy T. Kan ◽  
Mason B. Tomson
Keyword(s):  
Polycarboxylic Acid ◽  
Scale Inhibitor ◽  
Return Behavior ◽  
Mineral Scale ◽  
Scale Control

Evaluation of the transport and return behavior of phosphino-polycarboxylic acid modified scale inhibitor nanomaterial for oilfield mineral scale control.

Calcite Scale Mitigation in a Very Low Watercut, Low Salinity, HPHT Environment: Lessons Learned in Surveillance, Mitigation and Scale Inhibitor Performance Monitoring for an Onshore Field

2021 ◽  
Author(s):  
Jonathan J. Wylde ◽  
Alexander R. Thornton ◽  
Mark Gough ◽  
Rifky Akbar ◽  
William A. Bruckmann
Keyword(s):  
High Temperature ◽  
Calcium Carbonate ◽  
Laboratory Testing ◽  
Lessons Learned ◽  
Management Decision ◽  
Scale Inhibitor ◽  
Monitoring Programs ◽  
Mineral Scale ◽  
Water Cut ◽  
Scale Control

Abstract A prolific Southeast Asia onshore oilfield has enjoyed scale free production for many years before recently experiencing a series of unexpected and harsh calcite scaling events. Well watercuts were barely measurable, yet mineral scale deposits accumulated quickly across topside wellhead chokes and within downstream flowlines. This paper describes the scale management experience, and the specific challenges presented by this extraordinarily low well water cut, low pH, calcium carbonate scaling environment. To the knowledge of the authors, no previous literature works have been published regarding such an unusual and aggressive mineral scale control scenario. A detailed analysis of the scaling experience is provided, including plant layout, scaling locations, scale surveillance and monitoring programs, laboratory testing, product selection and implementation, and scale inhibitor efficacy surveillance and monitoring programs. The surveillance and application techniques themselves are notable, and feature important lessons learned for addressing similar very low water cut and moderate pH calcium carbonate scaling scenarios. For example, under ultra-low watercut high temperature well production conditions, it was found that a heavily diluted scale inhibitor was necessary to achieve optimum scale control, and a detailed laboratory and field implementation process is described that led to this key learning lesson. The sudden and immediate nature of the occurrence demanded a fast-track laboratory testing approach to rapidly identify a suitable scale inhibitor for the high temperature topside calcium carbonate scaling scenario. The streamlined selection program is detailed, however what could not be readily tested for via conventional laboratory testing was the effect of <1% water cut, and how the product would perform in that environment. A risk-managed field surveillance program was initiated to determine field efficiency of the identified polymeric scale inhibitor and involved field-trialing on a single well using a temporary restriction orifice plate (ROP) to modify the residence time of the injected chemical. The technique proved very successful and identifed that product dispersibility was important, and that dilution of the active scale inhibitor had a positive effect on dispersibility for optimum inhibitor action. The lessons learned were rolled out to all at-risk field producers with positive results. The ongoing success of this program continues and will be detailed in the manuscript and presentation. This paper demonstrates a unique situation of calcium carbonate scale formation and control that utilized a previously unreported and analytical surveillance approach. The cumulative performance derived by improving not only chemical selection, but the way the wells were managed via surveillance and chemical management decision making processes is compelling and of value to other production chemists working in the scaling arena.

Transport and return of an oilfield scale inhibitor reverse micelle nanofluid: impact of preflush and overflush

RSC Advances ◽  
2016 ◽  
Vol 6 (71) ◽  
pp. 66672-66681 ◽  
Author(s):  
Ping Zhang ◽  
Gedeng Ruan ◽  
Dong Shen ◽  
Amy T. Kan ◽  
Mason B. Tomson
Keyword(s):  
Reverse Micelle ◽  
Systematic Evaluation ◽  
Scale Inhibitor ◽  
Return Behavior ◽  
Mineral Scale ◽  
Scale Control

Systematic evaluation of the transport and return behavior of a Ca–DTPMP reverse micelle nanomaterial and nanofluid for oilfield mineral scale control.

Pre-Production Deployed Scale Inhibition Treatments in Deep-Water, West Africa

2014 ◽  
Author(s):  
D.. Patterson ◽  
W.. Williams ◽  
M.. Jordan ◽  
R.. Douglas
Keyword(s):  
West Africa ◽  
Deep Water ◽  
Best Practice ◽  
Barium Sulphate ◽  
Scale Inhibitor ◽  
Monitoring Methods ◽  
Initial Water ◽  
Scale Inhibition ◽  
Production Wells ◽  
Scale Control

Abstract The injection of seawater into oil-bearing reservoirs in order to maintain reservoir pressure and improve secondary recovery is a well-established, mature operation. Moreover, the degree of risk posed by deposition of mineral scales (carbonate/sulphate) to the injection and production wells during such operations has been much studied. The current deep-water subsea developments offshore West Africa and Brazil have brought into sharp focus the need to manage scale in an effective way. In a deepwater West African field the relatively small number of high-cost, highly productive wells, coupled with a high barium sulphate scaling tendency upon breakthrough of injection seawater meant not only was effective scale management critical to achieve high hydrocarbon recovery, but even wells at low water cuts have proven to be at sufficient risk to require early squeeze application. To provide effective scale control in these wells at low water cuts, phosphonate-based inhibitors were applied as part of the acid perforation wash and overflush stages prior to frac packing operations. The deployment of this inhibitor proved effective in controlling barium sulphate scale formation during initial water production eliminating the need to scale squeeze the wells at low water cuts (<10% BS&W). To increase the volumes of scale inhibitor being deployed in the pre-production treatments and so extend the treatment lifetimes scale inhibitor was also added to the frac gel used to carry the frac sand. This paper outlines the selection methods for the inhibitor chemical for application in frac fluids in terms of rheology, retention/release, formation damage and presents the chemical returns profile from the 5 wells treated (some treatments lasting > 300 days) along with monitoring methods utilized to confirm scale control in the wells treated. Many similar fields are currently being developed in the Campos basin, Gulf of Mexico, and West Africa, and this paper is a good example of best-practice sharing from another oil basin.

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