The results of experimental field trials of the compositions for acid treatment and hydraulic fracturing in conditions Domaniс deposits of the Bavlinskoye field

2020 ◽  
Vol 7 ◽  
pp. 104-108
Author(s):  
R.S. Khisamov ◽  
◽  
I.S. Zakirov ◽  
E.F. Zakharova ◽  
A.A. Lutfullin ◽  
...  
2021 ◽  
Author(s):  
Joseph Ferrar ◽  
Philip Maun ◽  
Kenneth Wunch ◽  
Joseph Moore ◽  
Jana Rajan ◽  
...  

Abstract We report the design, operation and biogenic souring data from a first-of-its kind suite of High Pressure, High Temperature (HPHT) Bioreactors for hydraulically fractured shale reservoirs. These bioreactors vet the ability of microbial control technologies, such as biocides, to prevent the onset of microbial contamination and reservoir souring at larger experimental volumes and higher pressures and temperatures than have been previously possible outside of field trials. The bioreactors were charged with proppant, crushed Permian shale, and sterile simulated fracturing fluids (SSFF). Subsets of bioreactors were charged with SSFF dosed with either no biocide, tributyl tetradecyl phosphonium chloride (TTPC, a cationic surface-active biocide), or 4,4-dimethyloxazolidine (DMO, a preservative biocide). The bioreactors were shut in under 1,000-2,500 psi and elevated temperatures for up to fifteen weeks; hydrogen sulfide (H2S) and microbial counts were measured approximately once per week, and additional microbes were introduced after weeks three and five. Across two separate studies, the bioreactors containing no biocide soured within the first week of shut-in and H2S concentrations increased rapidly beyond the maximum detectable level (343 ppm) within the first three to six weeks of shut-in. In the first study, the bioreactors treated with TTPC soured within two weeks of shut-in (prior to the first addition of fresh microbes), and H2S concentrations increased rapidly to nearly 200 ppm H2S within the first six weeks of shut-in and beyond the maximum detectable level after fifteen weeks of shut-in. The bioreactors containing DMO did not sour during either study until at least the first addition of fresh microbes, and higher levels of the preservative biocide continued to prevent the biogenic formation of H2S even during and after the addition of fresh microbes. Microbial counts correlate with the H2S readings across all bioreactor treatments. The differentiation in antimicrobial activity afforded by the different types of biocide treatments validates the use of these simulated laboratory reservoirs as a biocide selection tool. This first-of-its-kind suite of HPHT Bioreactors for hydraulic fracturing provides the most advanced biocide selection tool developed for the hydraulic fracturing industry to date. The bioreactors will guide completions and stimulation engineers in biocide program optimization under reservoir-relevant conditions prior to beginning lengthy and expensive field trials.


2020 ◽  
Vol 19 (4) ◽  
pp. 2196-2207 ◽  
Author(s):  
Manabu Sakai ◽  
Kenichiro Kamohara ◽  
Hiroki Iura ◽  
Hiroshi Nishimoto ◽  
Kazuaki Ishioka ◽  
...  

1995 ◽  
Vol 1995 (1) ◽  
pp. 901-902 ◽  
Author(s):  
Kenneth Lee ◽  
Richard P.J. Swannell ◽  
Per Sveum ◽  
Michel Guillerme ◽  
François-Xavier Merlin ◽  
...  

ABSTRACT An experimental protocol has been developed for assessing the efficacy of bioremediation strategies for the treatment of petroleum contaminated shoreline sediments. It is a framework for the design of experimental field trials that enables independent organizations to compare the results of experiments conducted in different environments. Coordinated studies of this nature are needed to formulate operational guidelines for the application of bioremediation agents during oil spill response situations.


2012 ◽  
Vol 10 (5) ◽  
pp. 511-523 ◽  
Author(s):  
Sonia Gómez-Galera ◽  
Richard M. Twyman ◽  
Penelope A.C. Sparrow ◽  
Bart Van Droogenbroeck ◽  
René Custers ◽  
...  

Author(s):  
V.T. Litvin ◽  
◽  
K.V. Strizhnev ◽  
T.N. Shevchuk ◽  
P.V. Roshchin ◽  
...  

1935 ◽  
Vol 12 (5) ◽  
pp. 590-613 ◽  
Author(s):  
O. S. Aamodt ◽  
W. H. Johnston

Results are presented of tests conducted at the University of Alberta, Edmonton, during the years 1931–34, to determine the relative resistance of barley varieties to the covered smut disease caused by Ustilago hordei.Extensive field trials, including 138 varieties, carried out in 1931, with hulled seed gave inconclusive results owing to low infection percentages. Junior and Eureka, two naturally hulless varieties, evidenced high susceptibility with 66 and 42% infection respectively. Field tests of a number of standard varieties in 1932 in which the seed was dehulled with sulphuric acid, resulted in an increase in the percentage of smutted plants. Unfortunately, the acid treatment of the kernels caused a general impairment in germination which lessened somewhat the significance of the results obtained. In 1934, the comparative infections and stands of varieties grown from hulled, hand-dehulled, scarified and acid-dehulled seed were determined. The data were treated statistically by the analysis of variance method. Significant variations due to varieties, treatments and interaction of varieties and treatments were obtained with regard to both percentage infection and percentage stand. All three of the dehulling measures increased smut infection significantly. Highest infection percentages resulted from hand-dehulled seed, followed by acid-dehulled and scarified seed in the order mentioned.The least reduction in stand resulted from hulled seed and the greatest from acid-dehulled seed. Scarified and hand-dehulled seed gave stands intermediate in numbers. Distinct varietal differences existed in thickness of hull or in the resistance of the hull to acid treatment. The average percentage stands of the different varieties tended to be directly proportional, and the average percentage smut infection inversely proportional to the amount of hull remaining on the kernels following acid treatment. Varieties grown from acid-dehulled and scarified seed were found to be delayed in heading [Formula: see text] and [Formula: see text] days respectively as compared with varieties grown from hulled or hand-dehulled seed, There was a tendency for the later varieties to be more susceptible to covered smut than the earlier ones.The varieties used in these investigations differed greatly in their reaction to covered smut. A fair degree of correlation was found to exist between the varietal infection percentages induced in 1932 by acid-dehulled seed and those induced by either hand-dehulled or acid-dehulled seed in 1934.Two distinct physiologic forms of U. hordei were found in collections gathered from six points in central Alberta. These are readily distinguished by their reaction on the varieties Eureka and Canadian Thorpe or Hannchen.From the experimental data it was concluded that the following varieties showed resistance to covered smut:Six-rowed, hulled types—O.A.C. No. 21, Atlas, Sacramento Glabron, Velvet, Leiorrhynchum, Wisconsin Barbless No. 38, Shaw, Sol and Success.Two-rowed, hulled types—Spartan, Golden Pheasant and Horn.Hulless types—Himalayan, New Era, Russian, Mongolian and Burbank.The following varieties showed susceptibility to one or more of the smut collections used:Six-rowed, hulled types—Bearer, Lapland, Star, Manchurian, Peatland, Trebi, Silver King, Vaughn, Comfort, Regal, Newal and Colsess.Two-rowed, hulled types—Binder, Canadian Thorpe, Duckbill, Gold, Hannchen, Swanneck and Charlottetown.Hulless types—Junior, Eureka, Improved White Hulless and Trifurcatum.


2021 ◽  
Author(s):  
Mustafa Ahmed Alkhowaildi ◽  
Mohamed Mahmoud ◽  
Mohammed Abdullah Bataweel ◽  
Bassam Tawabini

Abstract Amid the rise in energy demand over recent years, natural gas from tight reservoirs has been targeted abundantly around the globe by different oil operators. Hydraulic fracturing technology has been instrumental in the successful exploitation of energy from tight formations. The process is associated with enormous usage of water. Hydraulic fracturing requires as little as 500,000 gallons of freshwater, and up to 6 million gallons per well depending on the type of well and the number of stages treated. Now operators, as well as service companies worldwide, have shown a desire to use produced water in field operations to enhance economics and reduce their environmental footprint. Reusing produced water in field operations appears to be a win-win proposition by transforming the industry's biggest waste product into a resource. This paper highlights the recent findings in published articles about formulating a fracturing fluid from produced water as a base fluid. The rheological properties and fluid performance requirements, such as proppant carrying capacity, mixing, fluid efficiency, ability to crosslink and break, and cleanup after treatment, will be evaluated in detail. This paper identified the critical parameters associated with high TDS fluids (produced water) such as pH, hydration time, ionic strength, and suspended solids, collected the corresponding optimal ranges for these parameters in laboratory tests, and reported some of the validity of the findings under actual conditions in field trials around the world. Most studies demonstrated the feasibility of using untreated produced water as a base fluid for crosslinked gel-based hydraulic fracturing. Through adjusting the hydration time, the gel loading, and the amount of breakers applied, it is conceivable that crosslinked gels with optimal rheological characteristics can be formulated with untreated produced water. Multiple generations of guar- and CMHPG-based crosslinked fracturing fluids, developed with 100% untreated produced water, exhibited optimal viscosities exceeding 200 cp at 40 s−1 for at least 60 minutes. The ability to provide fracturing fluids with high-salinity produced water can be a successful water conservation approach and an attractive solution for enhancing operation economics. Some studies indicated that using produced water can be better than freshwater because the produced water is more compatible with the reservoir and may be less likely to cause conditions such as salinity shock, which can damage the formation. More studies are needed to understand the associated technical challenges further.


2021 ◽  
Author(s):  
Carl Harman ◽  
Michael McDonald ◽  
Paul Short ◽  
William Ott

Abstract The use of freshwater, near freshwater, or treated water in hydraulic fracturing represents an ever-increasing cost in the Permian Basin. Environmental concerns add to the pressure to develop methods to use significantly higher volumes of produced water in hydraulic fracture fluids. To solve the challenge of viscosifying untreated, high total dissolved solids water a move was made away from organic-based viscosifiers to silica-based technology. Fumed silica is highly effective as a viscosifier for high-density brines that has demonstrated excellent low-end rheology, exceptional suspending ability, and a nominal filter cake. However, the high cost of fumed silica and operational challenges have precluded commercial adoption. This paper describes thatsimilar rheology is achievable at a fraction of the cost using a silica gel. The focus of the paper is on the field trials in West Texas where untreated produced water was viscosified with silica gel and run as alternatives to a standard 20 lb/Mgal crosslinked guar fluid made with fresh water. Low cost and operational efficiencies were obtained bypreparingthe silica gel on-location using standard and readily available hydraulic fracturing equipment. Procedures for making the silica gel-based frac fluid were similar to those of making a crosslinked guar fluid. Field trials have demonstrated that silica-gel carries high loadings of 20/40 mesh sand even at low pump rates. Production data from the trials has varied from exceeding expectations to being similar to existing production results.On a chemical cost basis, silica gel is comparable to a borate-cross-linked guar frac fluid. The economics tip very much in favor of silica gel when factoring in the savings using untreated produced water.


Crop Science ◽  
2008 ◽  
Vol 48 (1) ◽  
pp. 49-58 ◽  
Author(s):  
Mark E. Halsey ◽  
Kenneth M. Olsen ◽  
Nigel J. Taylor ◽  
Paul Chavarriaga-Aguirre

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