Geology. Geophysics. Drilling
THE STUDY OF THE PRODUCTION BATCHES OF THE REAGENT TYLOSE WATER CHEMISTRY AND ENVIRONMENTALLY FRIENDLY LUBRICANT ADDITIVES FLOTATION-OXAL FOR DRILLING FLUIDS
The influence of commercial batch samples of reagent water chemistry Tilose made by the company “Hoechst AG” (Germany) for the basic and special properties of bentonite suspensions and drilling natural polimergranita drilling fluids oil and gas region of Western Siberia. Given information about physical-chemical properties of sodium carboxymethyl cellulose (CMC), a reagent Tylose water chemistry.
Acceptable additive reagent Tilose of water lead to a sufficient reduction of the filtration rate of clay solutions. However, the structural-rheological properties of clay solutions increase less than the reagent Tilose EC-7. Results of the effect of additives reagent Tilose of water in mixed solution (from the waste at the wells, followed by enrichment of bentonite clay solution).
The laboratory findings of the two compared quantities of reagents Tilose of water arrived at different times, comparable in terms of impact on the properties of clay solutions, which indicates compliance with the same synthesis technology and production of the reagent.
Additionally, a study conducted for the joint processing of drilling mud reagent Tylose water chemistry and reagents Nа2CО3, NTF, NGL-11. Natural drilling fluids, selected wells were treated in the polymeric reagent Whom Paz, lubricant additive flotation-oxal, and other Data established solutions were subjected to tempering. In some cases, the solution treated with reagent Tylose water chemistry, reduced structural-mechanical and rheological properties, but the rate of filtration of the solutions after incubation are not increased. In precoat solution treated with reagent NGL-11, increased colloidal clay component of the solution, as it has peptizyme action.
The study is based on the effects of carboxymethyl starch reagent KMK-Bur-N – Carboxymethyl starch reagent KMK-Bur-N is an additive to water-based drilling fluids for regulating filtration, structural, mechanical and rheological parameters in the manifestation of mineralized mineral waters containing Ca ++ and Mg ++ ions. KMK Bur-N reagent is produced according to TU 2262-016-32957739-01 by the company CJSC “Polycell” (Vladimir, Russia). Carboxymethyl starch is a chemical product of the interaction of starch with sodium mono chloroacetate in an aqueous solution of sodium hydroxide. The KMK-Bur-N reagent can also be used as part of process fluids for well completion and workover. Details are given on the physicochemical properties of KMK Bur-N reagent.
The addition of the KMK-Bur-N reagent to the bentonite suspension leads to a decrease in the filtration index, as well as an increase in the conventional viscosity, plastic and effective viscosity, dynamic and static shear stress. In addition, the KMK-Bur-N reagent can also be used for the chemical treatment of water-based natural polymer-clay drilling fluids produced in wells. Acceptable additives of KMK-Bur-N reagent in clay muds are in the range of 0.3-0.5%. Carboxymethyl starches are compatible with carboxymethylcellulose reagents and other reagents that are used to treat water-based drilling fluids in the Noyabrsk region of Western Siberia. Virtually all types of starch reagents, including the chemical product KMK-Bur-N are easily destroyed by acid treatment and subsequently removed from the productive formation in the event of formation damage during drilling or workover of wells.
REASONS EQUIPMENT FAILURE LOWER PART OF MULTISTAGE FRACTURING SYSTEM THE DESCENT INTO THE UNCASED HORIZONTAL WELLS
Today, due to the difficult economic situation in the country and in the oil industry, the development of new wells became ineffective. In recent years, oil companies significantly increase the amount of work on construction and reconstruction of wells in order to intensify and improve the technical and economic indicators. Problem fields with small reserves and low reservoir properties for our country is not relevant until you run out of the rich fountains of giant deposits. However, today, when the depletion of the resource base – a trend that the work on the fields with low-permeability reservoirs has become a serious challenge, require additions of standard methods of developing new approaches and technologies. Therefore, the problem of increasing technical and economic indicators of the exploited wells in recent years has become very urgent. The technology allows the development of the deposit with low-permeability reservoirs, is a multi-stage hydraulic fracturing. Unfortunately, this strategically important area of oilfield services today is controlled by foreign operators and equipment suppliers. Therefore, one of the most important tasks is to develop the country’s own fleet of equipment MGRP that meets modern standards and regulations of the Russian mining companies.
The article analyzes the major domestic manufacturers of equipment for multi-stage hydraulic fracturing particularly marked advantages and disadvantages of the construction. Also revealed the reasons for which there is equipment failure at the bottom of the layout multi-stage hydraulic fracturing.
In the final part of the article the authors propose the bottom of the design layout, which can eliminate equipment failure.
Conclusions and recommendations for hardware developers.
PROMISING PERSPECTIVES OF OIL RE-EXPLORATION IN PALEOCENE SEDIMENTS OF BLAGODARNENSKAYA STRUCTURE IN STAVROPOL REGION
Stavropol Region is one of the oldest petroleum producing regions of the country. To date, much of its fields are depleted and prospects for the discovery of large hydrocarbon deposits have been exhausted. At the same time, there is still the possibility of opening small and medium-sized deposits localized in the source rock formations.
In the middle of the last century, similar deposits have been identified within Prikumsk-Tyulenevskiy (Praskoveyskoe, Achikulakskoye, Ozek-Suat and a number of other fields) and Chernolesskiy (Zhuravskoye, Vorobyevskoye) tectonic elements. However, these findings were largely spontaneous due to lack of approved and unified approach to the petrophysical evaluation of dedicated reservoirs from well logs. At the same time the experience of shale reservoirs studies, as well as the results of its implementation to evaluation of deposits of Zhuravsky-Vorobyevsky petroleum accumulation zone, allows to revise existing well log materials for deep wells of explorational and depleted structures, and to identify promising intervals for further re-exploration and testing.
In this work, Paleocene sediments of Blagodarnenskaya explorational structure of the Stavropol Region were studied. Despite the approval of the oil bearing of these deposits within the Prikumsk-Tyulenevskiy tectonic element and the positive signs of hydrocarbon saturation from initial well logs data, its evaluation and testing within Blagodarnenskaya structure dedicated to the North-Stavropol tectonic element, were not conducted. However, the results of well logs analysis performed by us with the use of interpretation technique approved on shale reservoirs of Zhuravsky-Vorobyevsky petroleum accumulation zone, as well as the core tests indicate the presence of oil-saturated reservoirs in the Paleocene sediments of Blagodarnenskaya structure.
The sum of the obtained results and confirmation of the oil saturation of Paleocene sediments on the other structures allows us to propose promising perspectives of re-exploration of the Paleocene deposits within Blagodarnenskaya structure. The presence of a large number of abandoned deep exploration wells suitable for the re-entry allows performing re-exploration by means of the existing wells fund without drilling a new one, what would significantly reduce costs and ensure the profitability of the operation in the event of success.
The results of investigations of the two samples of reagents carboxymethyl starch (KMC) and one sample of carboxymethylcellulose sodium technical grade CMC-9/N, the production of LLP “Cellulose Ethers” (Vladimir) for mining and geological, technical and technological conditions of the November oil and gas region of Western Siberia.
The first batch of CMC did not meet the quality performance indicators TU 6-55-221-1396-95, namely the nature of the dissolution. The kinematic viscosity of a 1% aqueous solution of the sample in the CMC received the order before production batch. Consequently KMC also differs from all test samples before KMC to influence the rheological, mechanical and structural properties of drilling fluids, the number of additives in muds. Recommended additives in this mud sample KMC should be increased by 1% or more.
Another sample corresponds to the KVM presented quality indicators for TU 6-55-221-1396-95 and refers to the high viscosity grades. This part can be used as structurant in formulations of drilling mud during drilling for conductor in an amount of 0.2-0.3%.
Experimental test CMC 9 / N corresponds to the data presented by advertising and a brand of low viscosity CMC. This grade CMC 9 / N can be used as a structurant in a composition of bentonite fluids while drilling a conductor in an amount of 0.3% or more, and drilling a main wellbore production tubing in an amount of not less than 0.5%.