Advancement Towards the Full-Field Implementation of Marmul Alkaline-Surfactant-Polymer in the Sultanate of Oman

2021 ◽  
Author(s):  
Dawood Al Mahrouqi ◽  
Hanaa Sulaimani ◽  
Rouhi Farajzadeh ◽  
Yi Svec ◽  
Samya Farsi ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Phase 1 ◽  
Recovery Efficiency ◽  
Sultanate Of Oman ◽  
Water Separation ◽  
Full Field ◽  
Oil Water Separation ◽  
Oil Water ◽  
New Formulation ◽  
Alkaline Surfactant Polymer

Abstract In 2015-2016, the Alkaline-Surfactant-Polymer (ASP) flood Pilot in Marmul was successfully completed with ∼30% incremental oil recovery and no significant operational issues. In parallel to the ASP pilot, several laboratory studies were executed to identify an alternative and cost-efficient ASP formulation with simpler logistics. The studies resulted in a new formulation based on mono-ethanolamine (MEA) as alkali and a blend of commercially available and cheaper surfactants. To expediate the phased full field development, Phase-1 project was started in 2019 with the following main objectives are confirm high oil recovery efficiency of the new ASP formulation and ensure the scalability and further commercial maturation of ASP technology; de-risk the injectivity of new formulation; and de-risk oil-water separation in the presence of produced ASP chemicals. The Phase 1 project was executed in the same well pattern as the Pilot, but at a different reservoir unit that is more heterogeneous and has a smaller pore volume (PV) than those of the Pilot. This set-up allowed comparing the performance of ASP formulations and taking advantage of the existing surface facilities, thus reducing the project cost. The project was successfully finished in December 2020, and the following major conclusions were made: (1) with the estimated incremental recovery of around 15-18% and one of the producers exhibiting water cut reversal of more than 30%, the new ASP formulation is efficient and will be used in the follow-up phased commercial ASP projects; (2) the injectivity was sustained throughout the entire operations within the target rate and below the fracture pressure; (3) produced oil quality met the export requirements and a significant amount of oil-water separation data was collected. With confirmed high oil recovery efficiency for the cheaper and more convenient ASP formulation, the success of ASP flooding in the Phase-1 project paves the way for the subsequent commercial-scale ASP projects in the Sultanate of Oman.

Research of Water Quality in Typical Low Permeability Oilfield Produced Water Treatment

2014 ◽  
Vol 556-562 ◽  
pp. 867-871
Author(s):  
Qiu Shi Zhao
Keyword(s):  
Water Quality ◽  
Oil Recovery ◽  
Treatment Process ◽  
Produced Water ◽  
Sewage Treatment ◽  
Oil Fields ◽  
Water Separation ◽  
Oil Water Separation ◽  
Oilfield Produced Water ◽  
Oil Water

It is significative to study sewage treatment process in low permeable oil fields. It could enhance the oil recovery. The water quality characteristics and oil/water separation characteristics were researched during different period process by GC-MS. It shows that there are about 108 kinds of organic matters, including 45 kinds of aliphatic hydrocarbon, 7 kinds of aine, 5 kinds of sulfocompound and 9 kinds of hexacyclic compounds, such as Benzene, phenol, naphthalene and anthracene. The percent of oil droplets which size was less than 10μm is 57.3%, compared to 91.6% which size was more than 50μm. It is difficult to separate the water and oil. The remaining oil was emulsified oil. The process was hard to decrease COD, and some pollutants were existed in water, such as Arsenic, Selenium, Mercury ,Cadmium and Cr6+. It is further proposed to optimize and develop this process to removal oil and suspended solids.

Instow: A Full-Field, Multipatterned Alkaline-Surfactant-Polymer Flood—Analyses and Comparison of Phases 1 and 2

2021 ◽  
pp. 1-15
Author(s):  
M. J. Pitts ◽  
E. Dean ◽  
K. Wyatt ◽  
E. Skeans ◽  
D. Deo ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Phase 1 ◽  
Water Injection ◽  
Phase 2 ◽  
Full Field ◽  
Two Phases ◽  
Original Oil In Place ◽  
Total Oil ◽  
Operation Cost ◽  
Alkaline Surfactant Polymer

Summary An alkaline-surfactant-polymer (ASP) project in the Instow field, Upper Shaunavon Formation in Saskatchewan, Canada, was planned in three phases. The first two multiwell pattern phases are nearing completion. Beginning in 2007, an ASP solution was injected into Phase 1. Phase 1 polymer drive injection began in 2011 after injection of 37% pore volume (PV) ASP solution. Coincident with the polymer drive injection into Phase 1, Phase 2 ASP solution injection began. Phase 2 polymer drive began in 2016 after injection of 55% PV ASP solution. Polymer solution injection for the polymer drives of both phases continues in both phases with Phase 1 and Phase 2 injected volumes being 55 and 42% PV as of August 2019, respectively. Phase 1 and Phase 2 oil cut response to ASP injection showed an increase of approximately four times from 3.2% to a peak of 13.0% for Phase 1 and Phase 2 oil cut increased from 1.8% to a peak of 14.8%, approximately eightfold. Oil rates increased from approximately 3200 m3/m (20 127 bbl/m) at the end of water injection to a peak of 8300 m3/m (52 220 bbl/m) in Phase 1 and from 1230 m3/m (7 736 bbl/m) to 6332 m3/m (39 827 bbl/m) in Phase 2. Phase 1 pattern analysis indicates that the PV of ASP solution injected varied from 13% to 54% PV of ASP. Oil recoveries after the start of ASP solution injection in the different patterns ranged from 2.3% original oil in place (OOIP) up to 21.3% OOIP with lower oil recoveries generally correlating with lower volumes of ASP solution injected. Wells in common to the two phases of the project show increased oil cut and oil rate responses to chemical injection from both Phases 1 and 2. Total oil recovery as of August 2019 is 60% OOIP for Phase 1 and 62% OOIP for Phase 2. Phase 1 economic analysis indicated chemical and operation cost was approximately CAD 26/bbl, resulting in the decision to move forward with Phase 2.

scholarly journals Application of Nano-Hydroxyapatite Derived from Oyster Shell in Fabricating Superhydrophobic Sponge for Efficient Oil/Water Separation

Molecules ◽  
2021 ◽  
Vol 26 (12) ◽  
pp. 3703
Author(s):  
Chao Liu ◽  
Su-Hua Chen ◽  
Chi-Hao Yang-Zhou ◽  
Qiu-Gen Zhang ◽  
Ruby N. Michael
Keyword(s):  
Oil Recovery ◽  
Superhydrophobic Surface ◽  
Oyster Shell ◽  
Contact Angles ◽  
Immersion Method ◽  
Water Separation ◽  
Promising Alternative ◽  
Recovery Capacity ◽  
Oil Water Separation ◽  
Oil Water

The exploration of nonhazardous nanoparticles to fabricate a template-driven superhydrophobic surface is of great ecological importance for oil/water separation in practice. In this work, nano-hydroxyapatite (nano-HAp) with good biocompatibility was easily developed from discarded oyster shells and well incorporated with polydimethylsiloxane (PDMS) to create a superhydrophobic surface on a polyurethane (PU) sponge using a facile solution–immersion method. The obtained nano-HAp coated PU (nano-HAp/PU) sponge exhibited both excellent oil/water selectivity with water contact angles of over 150° and higher absorption capacity for various organic solvents and oils than the original PU sponge, which can be assigned to the nano-HAp coating surface with rough microstructures. Moreover, the superhydrophobic nano-HAp/PU sponge was found to be mechanically stable with no obvious decrease of oil recovery capacity from water in 10 cycles. This work presented that the oyster shell could be a promising alternative to superhydrophobic coatings, which was not only beneficial to oil-containing wastewater treatment, but also favorable for sustainable aquaculture.

Assessment of Enhanced-Oil-Recovery-Chemicals Production and its Potential Effect on Upstream Facilities

SPE Journal ◽  
2019 ◽  
Vol 24 (03) ◽  
pp. 1037-1056 ◽  
Author(s):  
Abdulkareem M. AlSofi ◽  
Ali M. AlKhatib ◽  
Hassan A. Al-Ajwad ◽  
Qiwei Wang ◽  
Badr H. Zahrani
Keyword(s):  
Side Effects ◽  
Enhanced Oil Recovery ◽  
Corrosion Inhibition ◽  
Oil Recovery ◽  
Produced Water ◽  
Water Separation ◽  
Scale Inhibition ◽  
Chemical Eor ◽  
Oil Water Separation ◽  
Oil Water

Summary Review of past chemical-enhanced-oil-recovery (EOR) projects illustrates that chemical-EOR implementation can result in produced-fluid-handling issues. However, in all projects such issues were resolved, mainly through a combination of improved demulsifiers and oversized vessels. In previous work, we have demonstrated the potential of surfactant/polymer flooding for a high-temperature/high-salinity carbonate. In consideration of future plans to pilot the process, further assessments were conducted to evaluate any side effects of these EOR chemicals on upstream facilities and determine mitigation plans if needed. In this work, we initially conduct a critical review of past experience. Then, we investigate the surfactant/polymer compatibility with the additives used in processing facilities for demulsification and scale and corrosion inhibition as well as the possible effect of surfactant/polymer on oil/water separation, metal corrosion, and scale inhibition. For this purpose, we first perform a sensitivity-based simulation study to estimate the volumes of produced EOR chemicals. Second, a compatibility study is conducted to evaluate EOR chemical compatibility with oilfield additives (i.e., demulsifier, corrosion inhibitor, and scale inhibitor). Third, bottle tests are conducted using surfactant/polymer solutions prepared in both injection and produced water to evaluate the effect of EOR chemicals on oil/water separation. Separated-water qualities are also evaluated using solvent extraction followed by ultraviolet (UV) visibility testing. Fourth, static autoclave and dynamic rotating tests are performed to evaluate the possible side effects of EOR chemicals on corrosion inhibition. Finally, static bottle and dynamic tube tests are performed to evaluate the possible side effects of EOR chemicals on scale inhibition; these observations are supported by characterization of precipitates using environmental scanning electron microscopy (ESEM) and X-ray diffraction (XRD). Depending on simulation, the peak polymer and surfactant concentrations at the separation plant are 83 and 40 ppm, respectively. The sensitivity study suggests a worst-case scenario in which peak polymer and surfactant concentrations of 174 and 128 ppm are produced. Compatibility testing confirms the compatibility of EOR chemicals with the additives used in upstream facilities. In those tests, neither precipitation nor phase separation is observed. Bottle tests indicate an overall negligible effect on oil/water-separation speed. However, analyses of separated-water quality indicated a noteworthy deterioration in separated-water qualities. Oil-in-water concentrations increase from 100 to 750 ppm and from 300 to 450 ppm at injection- and produced-water salinities, respectively. Furthermore, corrosion tests suggest that surfactant/polymer presence results in a significant reduction in corrosion rates by 70 and 86% at static and dynamic conditions, respectively, without any pitting issues. Finally, static and dynamic scale-inhibition studies performed at exacerbated conditions suggest that EOR chemicals can reduce the effectiveness of scale inhibitors. In static scaling tests, the effectiveness of the base polyacrylate inhibitor diminishes completely. However, the same degree of inhibition was achieved by switching to phosphonate inhibitors, but at a slightly higher dosage between 5 and 15 mg/L. In dynamic scaling tests, the base polyacrylate inhibitor failed at all tested dosages up to 100 mg/L. However, the alternative phosphonate inhibitors passed at dosages between 20 and 45 mg/L. Such effects can be attributed to changes in scale morphology and polymorphs, as demonstrated by the XRD and ESEM results. On the basis of those results, we conclude that the selected surfactant/polymer implementation will have a manageable effect on separation facilities. Finally, this work provides an experimental protocol to evaluate the potential side effects of a chemical-EOR process on upstream facilities.

Three Phase Flow Simulations of an Oil Recovery Ship in Various Sea States

2007 ◽  
Author(s):  
Gu¨nther F. Clauss ◽  
Florian Sprenger ◽  
Sascha Kosleck ◽  
Robert Stu¨ck
Keyword(s):  
Oil Recovery ◽  
Three Dimensional ◽  
Separation Process ◽  
Phase Flow ◽  
Water Separation ◽  
Flow Simulations ◽  
Three Phase ◽  
Three Phase Flow ◽  
Oil Water Separation ◽  
Oil Water

The analysis of local flow phenomena, in particular the analysis of the oil flow and the oil-water separation process in a three phase flow simulation (air, water, oil), including the free water surface, is a basic need for the development of an efficient oil recovery system such as the Seaway Independent Oilskimming System (SOS). As the oil separation process is highly dependent on the ships motions, its seakeeping behaviour needs to be simulated accurately. The paper presents two-phase flow simulations (air, water) of the seakeeping behaviour in three and six degrees of freedom (two- and three-dimensional — 2D/3D). The vessel motions simulated in various sea states are validated by model tests conducted in a physical wave tank. The grid resolution as well as the flow parameters of the simulation have been varied to find a fast and reliable solution. The need for three dimensional simulation runs is questioned, as two dimensional simulations give nearly the same results and are far less time intensive. Oil is introduced as the third phase. The associated analysis illustrates the oil-water separation process and yields the systems efficiency in dependency of the sea state conditions. Based on the results of three-phase simulations, the operational range of the Seaway Independent Oilskimmer is determined and recommendations for the system optimization can be made.

Enhancing oil–solid and oil–water separation in heavy oil recovery by CO 2 ‐responsive surfactants

AIChE Journal ◽  
2020 ◽  
Vol 67 (1) ◽  
Author(s):  
Yi Lu ◽  
Rui Li ◽  
Rogerio Manica ◽  
Qingxia Liu ◽  
Zhenghe Xu
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Heavy Oil Recovery ◽  
Water Separation ◽  
Oil Water Separation ◽  
Oil Water
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