Evaluation of the Need for Scale Inhibitor Injection During Formation Water Production in a Subsea Gas Field Using Partly PH Stabilised Mono Ethylene Glycol

2020 ◽  
Author(s):  
Anne Marie Koren Halvorsen ◽  
Kristin Hauge ◽  
Kari Straume Andersen ◽  
Baard Kaasa
Keyword(s):  
Ethylene Glycol ◽  
Water Production ◽  
Formation Water ◽  
Scale Inhibitor ◽  
Gas Field

Evaluation and application of calcite scale inhibitor in an offshore pH stabilised MEG system—an Australian first

2015 ◽  
Vol 55 (1) ◽  
pp. 247 ◽  
Author(s):  
Farrell Backus ◽  
Evan Harvey ◽  
Mike Gunn
Keyword(s):  
Production System ◽  
Closed Loop ◽  
Regeneration Process ◽  
Water Production ◽  
Formation Water ◽  
Critical Component ◽  
Scale Inhibitor ◽  
Regeneration System ◽  
Reduced Frequency ◽  
Harsh Conditions

Calcite scale mitigation in pH stabilised MEG systems is a growing concern for the industry as a number of systems are planned for upcoming Australian gas projects. Issues are insignificant at first gas when water of condensation is present. When formation water production occurs, scale management becomes a critical component of project feasibility. A closed loop pH stabilised MEG regeneration system located in the Otway Basin faced these challenges. Severe calcite scaling in a subsea well, which led to choke failure and MEG system fouling, was successfully controlled by the application of a specific polymeric scale inhibitor. The operating nature of a pH stabilised closed loop MEG system eliminates conventional scale inhibitor chemistries. Customised polymer chemistries were selected for review predominately due to their ability to persist in a variety of harsh conditions, including the MEG regeneration process. Technical qualification to validate scale inhibitor functionality was completed using protracted compatibility testing and Dynamic Scale Loop assessment. Evaluation of inhibitor performance and behaviour was accomplished using customised monitoring processes focusing on scale inhibitor detection, identifying measurement interferences, and interaction with precipitated solids. Field implementation provided excellent results with the inhibitor averting further severe scaling issues, resulting in minimal production system disruption. Fouling of the MEG regeneration system in particular has been minimised, resulting in a reduced frequency and length of cleaning cycles. This peer-reviewed paper will detail the evaluation, application and monitoring fundamentals when introducing scale inhibitors into pH stabilised MEG systems.

scholarly journals Pilot test of study on brine injection into shallow formation for mitigating land subsidence in the Southern Kanto Gas Field in Japan

2020 ◽  
Vol 382 ◽  
pp. 787-790
Author(s):  
Noriyuki Muraoka ◽  
Yuji Hayashi ◽  
Katsuhiro Nakamura ◽  
Toshiaki Yamaguchi ◽  
Kazunori Ono ◽  
...  
Keyword(s):  
Natural Gas ◽  
Land Subsidence ◽  
Ground Level ◽  
Pilot Test ◽  
Formation Water ◽  
Gas Field ◽  
Bottom Hole ◽  
Test Study ◽  
Water Formation ◽  
Brine Injection

Abstract. In the Southern Kanto Gas Field, natural gas dissolved in water has been produced for over 80 years. In order to produce the natural gas dissolved in water, formation water must be pumped from a reservoir in the gas field. The production of formation water is considered to be one of the causes of land subsidence. Because brine injection into shallow formations is expected to be effective to mitigate land subsidence, our association is planning to conduct the pilot test study. In this test, the production and injection of brine are going to be performed, and we will observe a deformation of the shallow formation and a change of ground level and the bottom hole pressure. As a result of these tests, if the land subsidence mitigation effect by injection into shallow formation is confirmed, it is expected that it will be connected to increased production and to reservoir management in consideration of land subsidence mitigation in the future.

scholarly journals The inhibition performance of mono-ethylene glycol on corrosion rate of x-80 grade carbon steel in saturated brine environment.

2020 ◽  
Vol 1 (1) ◽  
Keyword(s):  
Acetic Acid ◽  
Charge Transfer ◽  
Carbon Steel ◽  
Corrosion Rate ◽  
Ethylene Glycol ◽  
Oil And Gas ◽  
Gas Production ◽  
Electrochemical Measurements ◽  
Co2 Corrosion ◽  
Formation Water

The formation/deposition of hydrate and scale in gas production and transportation pipeline has continue to be a major challenge in the oil and gas industry. Pipeline transport is one of the most efficient, reliable and safer means of transporting petroleum products from the well sites to either the refineries or to the final destinations. Acetic acid (HAc), is formed in the formation water which also present in oil and gas production and transportation processes. Acetic acid aids corrosion in pipelines and in turn aids the formation and deposition of scales which may eventually choke off flow. Most times, Monethylene Glycol (MEG) is added into the pipeline as an antifreeze and anticorrosion agent. Some laboratory experiments have shown that the MEG needs to be separated from unwanted substance such as HAc that are present in the formation water to avoid critical conditions in the pipeline. Internal pipeline corrosion slows and decreases the production of oil and gas when associated with free water and reacts with CO2 and organic acid by lowering the integrity of the pipe. In this study, the effect of Mono-Ethylene Glycol (MEG) and Acetic acid (HAc) on the corrosion rate of X-80 grade carbon steel in CO2 saturated brine were evaluated at 25oC and 80oC using 3.5% NaCl solution in a semi-circulation flow loop set up. Weight loss and electrochemical measurements using the linear polarization resistance (LPR) and electrochemical impedance spectroscope (EIS) were used in measuring the corrosion rate as a function of HAc and MEG concentrations. The results obtained so far shows an average corrosion rate increases from 0.5 to 1.8 mm/yr at 25oC, and from 1.2 to 3.5 mm/yr at 80oC in the presence of HAc. However, there are decrease in corrosion rate from 1.8 to 0.95 mm/yr and from 3.5 to 1.6mm/yr respectively at 25oC and 80oC on addition of 20% and 80% MEG concentrations to the solution. It is also noted that the charge transfer with the electrochemical measurements (EIS) results is the main corrosion controlling mechanism under the test conditions. The higher temperature led to faster film dissolution and higher corrosion rate in the presence of HAc. The EIS results also indicate that the charge transfer controlled behaviour was as a result of iron carbonate layer accelerated by the addition of different concentrations of MEG to the system. Key words: CO2 corrosion, Carbon steel, MEG, HAc, Inhibition, Environment.

scholarly journals Visible Research of Loading Speed in Vertical Gas Well

2015 ◽  
Vol 8 (1) ◽  
pp. 163-166
Author(s):  
Wang Xiuwu ◽  
Liao Ruiquan ◽  
Liu Jie ◽  
Wang Xiaowei
Keyword(s):  
Loading Rate ◽  
Water Production ◽  
Formation Water ◽  
Gas Wells ◽  
Liquid Loading ◽  
Gas Well ◽  
Rate Law ◽  
Rate Laws ◽  
Normal Production ◽  
The Stability

For gas well under certain conditions, formation water production is inevitable in the later development; Formation water production is harmful to the normal production, it may cause liquid loading, flooding or even stop production. Based on the study of liquid loading and the rate laws of liquid loading, taking corresponding measures for the gas well is important. Simulating formation liquid production of gas wells with single rate under wellbore conditions, observing and measuring liquid loading rate through the experiment, summing up the liquid loading rate law of wellbore, are significant to the stability of gas well.

Study on Source Analysis of the Cation in Produced Water from Sulige Gas Field and Anti-Scaling Measures

2019 ◽  
Vol 814 ◽  
pp. 505-510
Author(s):  
Peng Chang ◽  
Rui Xue Shi ◽  
Li Wang ◽  
Wei Han ◽  
Cong Dan Ye ◽  
...  
Keyword(s):  
Produced Water ◽  
Xrd Analysis ◽  
Source Analysis ◽  
Scale Inhibitor ◽  
Gas Wells ◽  
Gas Field ◽  
Gas Well ◽  
Strontium Sulfate ◽  
Single Well ◽  
Main Component

A large amount of foreign matter appears in the Sulige gas well, causing blockage and corrosion of the pipeline, increasing the pressure difference in the wellbore and seriously affecting the normal production of the gas well. The gas wells with serious conditions mentioned above were selected to analyze the quality of single well produced water and the composition of blockage and core. Combined with the XRD analysis results of the cuttings, the long-term leaching experiments on the cuttings in different simulated solutions were carried out to study the sources of scaled ions in the gas wells. The experimental results showed that the extracted water from SD6-1 had high salinity and high content of scale ions Ca2+, Ba2+ and Sr2+;the main component of blockage is the acid insoluble strontium sulfate (barium) scale, and contains a small amount of corrosion products. The easily scalable Ca2+、Mg2+、Ba2+ and Sr2+ produced from the dissolution of the core in the formation water or working fluids, especially the acid erosion dissolves. According to the scaling mechanism, two kinds of Sr/Ba scale inhibitor were selected. The results showed that the barium II scale inhibitor performance is relatively good, and at the concentration of 40 mg/L, and the scale inhibition rate was more than 95%. The clogging of a single well can be reduced by adding a scale inhibitor.

scholarly journals Application of a Zwitterionic Hydrophobic Associating Polymer with High Salt and Heat Tolerance in Brine-Based Fracturing Fluid

Polymers ◽  
2019 ◽  
Vol 11 (12) ◽  
pp. 2005 ◽  
Author(s):  
Jizhen Tian ◽  
Jincheng Mao ◽  
Wenlong Zhang ◽  
Xiaojiang Yang ◽  
Chong Lin ◽  
...  
Keyword(s):  
Strong Association ◽  
Common Salt ◽  
Formation Water ◽  
Fracturing Fluid ◽  
Gas Field ◽  
High Salinity Water ◽  
Matrix Permeability ◽  
Fracturing Fluids ◽  
Polyelectrolyte Effect ◽  
Associating Polymer

ZID16PM, a zwitterionic hydrophobic associating polymer, has equivalent positive and negative charges and some hydrophobic monomers with twin-tailed long hydrophobic chains. It exhibits a great heat resistance and salt tolerance to the common salt in formation brine (MgCl2, CaCl2, NaCl, and KCl), which is attributed to its anti-polyelectrolyte effect and strong association force. High-salinity water (seawater or formation water) can be prepared as a fracturing fluid directly. In this paper, the formation water of the West Sichuan Gas Field is directly prepared into fracturing fluid with a concentration of 0.3% ZID16PM (Fluid-1), and the seawater of the Gulf of Mexico is directly prepared into fracturing fluid with a concentration of 0.3% ZID16PM (Fluid-2). Finally, rheological measurements, proppant suspension tests, and core matrix permeability damage rate tests for the Fluid-1 and Fluid-2 are conducted. Results show that after 120 min of shearing at 140 and 160 °C, respectively, the viscosity of Fluid-1 remains in the range of 50–85 mPa·s, and the viscosity of Fluid-2 remains in the range of 60–95 mPa·s. And the wastewater produced by an oilfield in Shaanxi, Xinjiang, and Jiangsu are also prepared into fracturing fluids with a concentration of 0.3% ZID16PM, the viscosity of these fracturing fluids can remain 32, 42, and 45 mPa·s, respectively, after 120 min of shearing at 160 °C. All results demonstrate that the polymer ZID16PM displays prominent performance in fracturing fluids.

Evaluation and application of poly(ethylene glycol) as lubricant in water‐based drilling fluid for horizontal well in Sulige Gas Field

2020 ◽  
Vol 70 (1) ◽  
pp. 83-89 ◽  
Author(s):  
Xiongxiong Liu ◽  
Long Gao ◽  
Qingchen Wang ◽  
Xuefan Gu ◽  
Weichao Du ◽  
...  
Keyword(s):  
Ethylene Glycol ◽  
Horizontal Well ◽  
Drilling Fluid ◽  
Poly Ethylene Glycol ◽  
Gas Field ◽  
Water Based ◽  
Poly Ethylene

A New Experimental Evaluation Technology for Foaming Agent in High Temperature and High Pressure Formation

2014 ◽  
Vol 962-965 ◽  
pp. 877-882
Author(s):  
Guang Qiang Cao ◽  
Yun Wang ◽  
Nan Li
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Experimental Evaluation ◽  
Evaluation Method ◽  
Water Production ◽  
Gas Field ◽  
Foaming Agent ◽  
Influence Of Temperature ◽  
Temperature Range ◽  
Temperature And Pressure

Foaming deliquification is one of the most widely used technologies in the development of water production gas field. The key of this technology is the experimental optimization or develop the foaming agent suitable for gas field. With the development of a large number of high temperature and high pressure gas field, foam experimental evaluation methods used at present can not satisfy the temperature range of high temperature and high pressure evaluation requirements, in this case, used the Ross-Miles foam evaluation method as the foundation, built a new experimental evaluation method for foaming agent. Through an example, analyzes the influence of temperature and pressure on the foaming agent performance.

scholarly journals Experimental evaluation and tomographic characterization of polymer gel conformance treatment

2020 ◽  
Vol 75 ◽  
pp. 65
Author(s):  
Mina Kalateh-Aghamohammadi ◽  
Jafar Qajar ◽  
Feridun Esmaeilzadeh
Keyword(s):  
Pore Space ◽  
Ct Images ◽  
Water Salinity ◽  
Water Production ◽  
Polymer Gel ◽  
Formation Water ◽  
High Permeability ◽  
Conformance Control ◽  
Formation Water Salinity ◽  
Excessive Water

Excessive water production from hydrocarbon reservoirs is considered as one of major problems, which has numerous economic and environmental consequences. Polymer-gel remediation has been widely used to reduce excessive water production during oil and gas recovery by plugging high permeability zones and improving conformance control. In this paper, we investigate the performance of a HPAM/PEI (water-soluble Hydrolyzed PolyAcrylaMide/PolyEthyleneImine) polymer-gel system for pore space blockage and permeability reduction for conformance control purpose. First, the gel optimum composition, resistance to salt and long life time are determined using bottle tests as a standard method to specify polymer-gel properties. Then the performance and stability of the optimized polymer-gel are tested experimentally using coreflood tests in sandpack core samples. The effects of different parameters such as gel concentration, initial permeability of the cores, and formation water salinity on the final permeability of the cores are examined. Finally, the gel flow-induced local porosity changes are studied in both a sandpack core and a real carbonate sample using grayscale intensity data provided from 3D Computed Tomography (CT) images in pre- and post-treatment states. The results show that the gel system has a good strength at the middle formation water salinity (in the range of typical sea water salinity). In addition, despite a higher performance in high permeability cores, the gel resistance to degradation in such porous media is reduced. The CT images reveal that the initial porosity distribution has a great influence on the performance of the gel to block the pore space.

Sign in / Sign up

Export Citation Format

Share Document