Development plan for the Karakudyk deposit. Business plan for the development of the Egoryevskoye building stone deposit Plan for the development of the deposit

The main graphic document when calculating reserves is the counting plan. Estimated plans (Fig. 3) are drawn up on the basis of a structural map for the top of productive strata-reservoirs or the nearest benchmark located no more than 10 m above or below the top of the stratum. The outer and inner contours are plotted on the map oil- and gas content, boundaries of reserves categories.

The boundaries and area of calculation of oil and gas reserves of each of the categories are colored in a specific color:

Rice. 3. An example of an estimated reservoir plan.

1 - oil; 2 - water: 3 - oil and water;

Wells: 4 - producing, 5 - exploration, 6 - suspended, 7 - abandoned, 8 - no inflow; 9 - isohypses of the collector surface, m;

Oil-bearing contours: 10 - external, 11 - internal; 12 - boundary of lithological-facies replacement of reservoirs; 13-categories of reserves;

Figures for wells: the numerator is the well number, the denominator is the absolute elevation of the reservoir top, m.

All wells drilled on the date of reserves calculation are also plotted on the calculation plan (with an exact indication of the position of the wellheads, the points of their intersection with the top of the corresponding reservoir):

Exploration;

Mining;

Mothballed pending the organization of the fishery;

Injection and observation;

Those who gave anhydrous oil, oil with water, gas, gas with condensate, gas with condensate and water and water;

Being tested;

Untested, with specification oil-, gas- and water saturation of reservoirs - reservoirs according to the interpretation of materials of geophysical studies of wells;

Liquidated, indicating the reasons for liquidation;

Revealed seam, composed of impermeable rocks.

For tested wells, the following are indicated: depth and absolute marks of the top and bottom of the reservoir, absolute marks of perforation intervals, initial and current oil production rates, gas and water, diameter of the choke, depression, duration of operation, date of appearance of water and its percentage in the produced product. When two or more layers are tested together, their indices are indicated. Debit oil and gas should be measured when the wells are operating on the same chokes.

For producing wells, the following are given: commissioning date, initial and current flow rates and reservoir pressure, oil produced, gas, condensate and water, the date of the beginning of watering and the percentage of water in the produced product as of the date of reserves calculation. With a large number of wells, this information is placed in the table on the calculation plan or on the sheet attached to it. In addition, the calculation plan contains a table indicating the values of the calculation parameters adopted by the authors, the calculated reserves, their categories, the values of the parameters adopted by the decision of the State Committee for the Reserves of the Russian Federation, the date on which the reserves were calculated.

When re-estimating reserves, the estimate plans should contain the boundaries of the reserves categories approved in the previous calculation, and wells drilled after the previous calculation of reserves should be highlighted.

The calculation of reserves of oil, gas, condensate and the components contained in them is carried out separately for gas, oil ,. gas-oil, water-oil and gas-oil-water zones by types of reservoirs for each stratum of the deposit and the field as a whole, with a mandatory assessment of the prospects for the entire field.

Reserves of commercially important components contained in oil and gas are calculated within the bounds of reserves estimate oil and gas.

When calculating reserves, the calculated parameters are measured in the following units: thickness in meters; pressure in megapascals (accurate to tenths of a unit); area in thousands of square meters; density of oil, condensate and water in grams per cubic centimeter, and gas - in kilograms per cubic meter (accurate to thousandths of a unit); porosity and oil and gas saturation coefficients in fractions of a unit rounded to the nearest hundredths; recovery factors oil and condensate in fractions of a unit rounded to the nearest thousandths.

The reserves of oil, condensate, ethane, propane, butanes, sulfur and metals are calculated in thousands of tons, gas - in millions of cubic meters, helium and argon - in thousands of cubic meters.

Average values of parameters and results of calculation of reserves are given in tabular form.

The organization was founded in December 2005. The operator of the project is KarakudukMunai LLP. LUKOIL's partner in the project is Sinopec (50%). The development of the deposit is carried out in accordance with the subsoil use contract signed on September 18, 1995. The contract is valid for 25 years. The Karakuduk field is located in the Mangistau region, 360 km from the city of Aktau. Remaining recoverable hydrocarbon reserves - 11 million tons. Production in 2011 - 1.4 million tons of oil (LUKOIL's share is 0.7 million tons) and 150 million cubic meters of gas (LUKOIL's share is 75 million cubic meters). Investments since the beginning of the project (since 2006) - more than $ 400 million in LUKOIL's share. The total number of employees is about 500 people, of which 97% are citizens of the Republic of Kazakhstan. LUKOIL plans to invest up to $ 0.1 billion in its share in the development of the project by 2020.

Proved oil and gas reserves (in the share of LUKOIL Overseas)
	million barrels
	bcf
Oil and gas	million barrels n. NS.
Marketable production per year (in the share of LUKOIL Overseas)
	million barrels

Oil and gas	million barrels n. NS.
Share of LUKOIL Overseas in the project *
Project participants
Project operator	LLP "Karakudukmunai"
Production well stock
Average daily flow rate of 1 well
Average daily flow rate of 1 new well

GENERAL DEPOSIT INFORMATION

Geographically, the Karakuduk field is located in the southwestern part of the Ustyurt plateau. Administratively it belongs to the Mangistau district of the Mangystau region of the Republic of Kazakhstan.

The nearest settlement is the Sai-Utes railway station, located 60 km to the southeast. Beineu station is located 160 km from the field. The distance to the regional center of Aktau is 365 km.

In orographic terms, the work area is a desert plain. The absolute elevations of the relief surface range from +180 m to +200 m. The work area is characterized by a sharply continental climate with hot dry summers and cold winters. The hottest summer month is July with a maximum temperature of up to +45 o C. In winter, the minimum temperature reaches -30-35 o C. The average annual rainfall is 100-170 mm. The region is characterized by strong winds turning into dust storms. In accordance with SNiP 2.01.07.85, the area of the deposit in terms of wind pressure belongs to the III area (up to 15 m / s). In summer, NW winds prevail, in winter - NW. The snow cover in the work area is uneven. The thickness in the most submerged low-lying areas reaches 1-5 m.

The fauna and flora of the region is poor and is represented by species typical for semi-desert zones. Rare herb and shrub vegetation is characteristic: camel thorn, wormwood, hodgepodge. The fauna is represented by rodents, reptiles (turtles, lizards, snakes) and arachnids.

There are no natural water sources in the area of work. Currently, the sources of water supply to the field drinking water The Volga water from the Astrakhan-Mangyshlak main water conduit is used for technical and fire-fighting needs, as well as special water wells up to 1100 m deep for the Albsenomanian sediments.

The work area is practically uninhabited. 30 km to the east of the Karakuduk deposit passes Railway Makat - Mangyshlak station, along which the existing oil and gas pipelines Uzen-Atyrau-Samara and Central Asia-Center, as well as the Beineu-Uzen high-voltage power line are laid. Communication between fishery and settlements carried out by road.

GEOLOGICAL AND PHYSICAL CHARACTERISTICS OF THE DEPOSIT

3.1. Characteristics of the geological structure

Lithological and stratigraphic characteristics of the section

As a result of exploration and production drilling at the Karakuduk field, a stratum of Meso-Cenozoic sediments with a maximum thickness of 3662 m (well 20), from Triassic to Neogene-Quaternary inclusive, was uncovered.

Below is a description of the exposed section of the field.

Triassic system - T. Variegated terrigenous strata of Triassic age is represented by alternating sandstones, siltstones, mudstones and mudstone-like clays, colored in various shades of gray, brown to greenish-gray. The minimum penetrated thickness of the Triassic is noted in well 145 (29 m) and the maximum - in well 20 (242 m).

Jurassic system - J. With stratigraphic and angular unconformity, a stratum of Jurassic deposits overlies the underlying Triassic rocks.

The Jurassic section is presented in the volume of the lower, middle and upper sections.

Lower section - J 1. The Lower Jurassic section is lithologically composed of interbedded sandstones, siltstones, clays and mudstones. Light gray sandstone with a greenish tint, fine-grained, poorly sorted, well-cemented. Clays and siltstones are dark gray with a greenish tint. Dark gray mudstones with ORO inclusions. Regionally, the Yu-XIII horizon is confined to the Lower Jurassic deposits. The thickness of the Lower Jurassic deposits ranges from 120-127m.

Middle department - J 2. The Middle Jurassic sequence is represented by all three stages: Bathonian, Bajocian, and Aalenian.

Aalenian Stage - J 2 a. Deposits of the Aalenian age overlie the underlying ones with stratigraphic and angular unconformity and are represented by alternating sandstones, clays, and, more rarely, siltstones. Sandstones and siltstones are colored in gray and light gray tones; clays are characterized by a darker color. In the regional relation to this stratigraphic interval, horizons J –XI, J – XII are confined. The thickness is over 100m.

Bayos tier - J 2 c. The sandstones are gray and light gray, fine-grained, strongly cemented, not grainy, micaceous. Light gray, fine-grained siltstones, micaceous, clayey, with inclusions of charred plant remains. Clays are dark gray, black, dense in places. The deposits of this age are associated with the productive horizons Yu-VI-Yu-X. The thickness is about 462m.

Bathsky tier - J 2 vt. Lithologically, they are represented by sandstones, siltstones, interbedded with clays. In the lower part of the section, the proportion of sandstones increases with thin layers of siltstones and clays. The deposits of the Bathonian stage are associated with the productive horizons Yu-III-Yu-V. Thickness varies from 114.8m to 160.7m.

Upper section - J 3. The deposits of the Upper Jurassic conformably lie on the underlying ones and are represented by three stages: Callovian, Oxfordian and Volga. The lower boundary is drawn along the top of the clay member, which is clearly traced in all wells.

Callovian Stage - J 3 K. The Callovian Stage is represented by alternating clays, sandstones and siltstones. According to the lithological features, three members are distinguished in the composition of the stage: the upper and middle ones are clayey with a thickness of 20-30 m, and the lower one is an alternation of layers of sandstones and siltstones with interlayers of clay. The productive horizons Yu-I and Yu-II are confined to the lower member of the Callovian Stage. The thickness ranges from 103.2m to 156m.

Oxford-Volga tier - J 3 ox-v. Sediments of the Oxfordian stage are represented by clays and marls with rare interlayers of sandstones and siltstones, while some differentiation is observed: the lower part is clayey, the upper part is marly.

The rocks are gray, light gray, sometimes dark gray, and have a greenish tint.

The section of the Volga time is a stratum of clayey limestones with interlayers of dolomites, marls and clays. Limestones are often fractured and porous, massive, sandy, clayey, with an uneven fracture and a matte sheen. Clays are silty, gray, calcareous, often with inclusions of fauna remains. Dolomites are gray, dark gray, cryptocrystalline, in places clayey, with an uneven fracture and a matte sheen. The thickness of the rocks ranges from 179m to 231.3m.

Cretaceous system - K. Deposits of the Cretaceous system are presented in the volume of the lower and upper sections. The section was subdivided into tiers based on logging materials and comparison with adjacent areas.

Lower section - K 1. The Lower Cretaceous deposits are composed of rocks of the Neocomian superstage, Aptian and Albian stages.

Neocomian superstage - K 1 ps. The underlying Volgian sediments are consistently overlain by the strata of the Neocomian interval, which unites three stages: Valanginian, Hauterivian, Barremian.

The section is lithologically composed of sandstones, clays, limestones and dolomites. Fine-grained sandstones, light gray, polymictic, with carbonate and clay cement.

At the level of the Hauterivian interval, the section is mainly represented by clays, marls, and only at the top is a sand horizon traced. The Barremian deposits are distinguished in the section by the variegated color of the rocks and are lithologically composed of clays with interlayers of sandstones and siltstones. Throughout the section of the Neocomian age, the presence of units of silty-sandy parods is observed. The thickness of the deposits of the Neocomian superstage ranges from 523.5 m to 577 m.

Aptian Stage - K 1 a. Deposits of this age overlap the underlying ones with erosion, having a clear lithological boundary with them. In the lower part, the section is composed mainly of clayey rocks with rare interlayers of sands, sandstones, siltstones, and in the upper part, a uniform alternation of clay and sandy rocks. The thickness varies from 68.7 m to 129.5 m.

Albian Stage - K 1 al. The section consists of interbedded sands, sandstones and clays. In terms of structural and textural features, the rocks do not differ from those below. The thickness varies from 558.5 m to 640 m.

Upper section - K 2. The upper section is represented by Cenomanian and Turonian-Senonian deposits.

Cenomanian stage - K 2 s. Cenomanian deposits are represented by clays alternating with siltstones and sandstones. In terms of lithological appearance and composition, the rocks of this age do not differ from the Albian deposits. The thickness ranges from 157m to 204m.

Turonian-Senonian undivided complex - К 2 t-cn. At the bottom of the described complex, the Turonian stage is distinguished, composed of clays, sandstones, limestones, chalk-like marls, which are a good benchmark.

Higher in the section, there are sediments of the Santonian, Campanian, Maastrichtian stages, united in the Senonian superstage, represented lithologically by a thick stratum of interbedded marls, chalk, chalk-like limestones and carbonate clays.

The thickness of the deposits of the Turonian-Senonian complex varies from 342m to 369m.

Paleogene system - R. Paleogene deposits are represented by white limestones, greenish marl strata, and pink siltstone clays. The thickness varies from 498m to 533m.

Neogene-Quaternary system - N-Q. Neogene-Quaternary deposits are composed mainly of light gray, green and brown carbonate-clay rocks and limestones - shell rocks. The upper part of the section is filled with continental sediments and conglomerates. The thickness of the deposits varies from 38 m to 68 m.

3.2. Tectonics

According to tectonic zoning, the Karakuduk field is located within the Arystan tectonic stage, which is part of the North Ustyurt system of troughs and uplifts of the western part of the Turan plate.

According to the seismic data of CDP-3D (2007) carried out by OJSC Bashneftegeofizika, the Karakuduk structure along reflecting horizon III is a brachyanticlinal fold of sub-latitudinal strike with dimensions of 9x6.5 km along a closed isohypse of minus 2195 m, with an amplitude of 40 m. The angles of incidence of the wings increase with depth: in the Turonian - a degree, in the Lower Cretaceous -1-2˚. The structure along reflecting horizon V is an anticlinal fold broken by numerous faults, possibly some of them of a non-tectonic nature. All major faults described further in the text are traced along this reflective horizon. The submeridional fold consists of two vaults, outlined by the isohypsum minus 3440 m, identified in the area of wells 260-283-266-172-163-262 and 216-218-215. Along the isohypse minus 3480 m, the fold has dimensions 7.4x 4.9 km and an amplitude of 40 m.

The uplift on structural maps along the Jurassic productive horizons has an almost isometric shape, complicated by a series of faults dividing the structure into several blocks. The most basic disturbance is F 1 disturbance in the east, which can be traced throughout the productive section, and divides the structure into two blocks: central (I) and eastern (II). Block II is lowered relative to block I with an increase in the amplitude of the displacement from south to north from 10 to 35 m. Violation of F 1 is oblique and moves from west to east with depth. This violation was confirmed by drilling well 191, where part of the Jurassic deposits of about 15 m at the level of the Yu-IVA productive horizon is absent.

Violation F 2 was carried out in the area of wells 143, 14 and cuts off the central block (I) from the southern block (III). The rationale for this violation was not only the seismic basis, but also the results of well testing. For example, from among the base wells near well 143, there is well 222, where oil was obtained during testing of the Yu-I horizon, and water was obtained in well 143.

Work description

Ministry Education and Science of the Republic of Kazakhstan

Finance and Economics Faculty

Department of Economics and Management

D
discipline: Evaluation of oil and gas projects

SRS No. 1

Topic: Development plan for the strategically important Kashagan field on the shelf of the Caspian Sea

Performed:

3-year student special "Economy"

Batyrgalieva Zarina

ID: 08BD03185

Checked:

Estekova G.B.

Almaty, 2010

Over the past 30 years, there have been trends in which world GDP is growing by an average of 3.3% per year, while world demand for oil as the main source of hydrocarbons is growing by an average of 1% per year. The lag in hydrocarbon consumption from GDP growth is associated with resource conservation processes, mainly in developed countries... At the same time, the share of developing countries in the production of GDP and in the consumption of hydrocarbons is constantly increasing. In this case, an increasing exacerbation of the problems of supply of hydrocarbons is expected.

The territorial proximity of such largest and dynamically developing countries as Russia and China opens up broad prospects for the export of Kazakhstani hydrocarbons. To ensure access to their market, it is necessary to develop and improve the system of trunk pipelines.

The assessments of international experts show that if the current trends continue, all the world's proven oil reserves will only last for 40-50 years. The addition of KSCM's petroleum resources to the world's proven reserves is a defining factor in global energy strategies. Kazakhstan should be ready for a flexible combination of strategies for the systematic transfer of oil production to the Caspian Sea and forcing certain promising projects. And one of the most promising projects is the Kashagan field.

Named after a 19th century Kazakh poet who was born in the Mangistau region, the Kashagan field is one of the world's largest discoveries over the past 40 years. Belongs to the Caspian oil and gas province.

The Kashagan field is located in the Kazakh sector of the Caspian Sea and covers an area of approximately 75 x 45 kilometers. The reservoir lies at a depth of about 4,200 meters below the seabed in the northern part of the Caspian Sea.

Kashagan, as a high-amplitude reef uplift in the subsalt Paleozoic complex of the North Caspian Sea, was discovered by prospecting seismic works by Soviet geophysicists in the period 1988-1991. on the sea continuation of the Karaton-Tengiz zone of uplifts.

Subsequently, it was confirmed by studies of Western geophysical companies commissioned by the government of Kazakhstan. The Kashagan, Koroghly and Nubar massifs, originally identified in its structure in the period 1995-1999. were named Kashagan East, West and South-West, respectively.

The dimensions of East Kashagan along the closed isohypse - 5000 m are 40 (10/25) km, area - 930 km², uplift amplitude - 1300 m km², the average oil-saturated thickness is 550 m.

Kashagan Western borders on Eastern Kashagan along a submeridional structural scarp, which is possibly associated with tectonic dislocation. The dimensions of the reef uplift along the closed stratoisohypse - 5000 m are 40 * 10 km, the area is 490 km², the amplitude is 900 m. , the average oil-saturated thickness is 350 m.

Southwestern Kashagan is located somewhat to the side (south) of the main massif. The uplift along the closed stratoisohypse - 5400 m has dimensions of 97 km, area - 47 km², amplitude - 500 m. OWC is predicted at an absolute mark of 5300 m, oil-bearing area - 33 km², average oil-saturated thickness - 200 m.

Kashagan's oil reserves vary widely from 1.5 to 10.5 billion tons. Of these, the Eastern accounts for 1.1 to 8 billion tons, the Western - up to 2.5 billion tons, and the South-Western - 150 million tons.

The geological reserves of Kashagan are estimated at 4.8 billion tons of oil according to Kazakh geologists.

According to the project operator, the total oil reserves are 38 billion barrels or 6 billion tons, of which about 10 billion barrels are recoverable. Kashagan has large reserves of natural gas over 1 trillion. cub. meters.

Partner companies in the Kashagan project: Eni, KMG Kashagan B.V. (a subsidiary of Kazmunaigaz), Total, ExxonMobil, Royal Dutch Shell each have a 16.81% stake, ConocoPhillips - 8.4%, Inpex - 7.56%.

The project operator was appointed in 2001 by partners: Eni, and created the Agip KCO company. The project participants are working on the creation of a joint operating company North Caspian Operating Company (NCOC), which will replace AgipKCO and a number of agent companies as a single operator.

The Kazakh government and the international consortium for the development of the North Caspian project (including the Kashagan field) agreed to postpone the start of oil production from 2011 to the end of 2012.

Oil production at Kashagan should reach 50 million tons per year by the end of the next decade. Oil production at Kashagan, according to ENI estimates, in 2019 should reach 75 million tons per year. With Kashagan, Kazakhstan will enter the Top 5 of the world's oil producers.

In order to increase oil recovery and reduce H3S content, the consortium is preparing to use several onshore and offshore installations in Karabatan to inject natural gas into the reservoir, an oil pipeline and a gas pipeline with Karabatan will be built.

The development of the Kashagan field in the harsh offshore environment of the North Caspian presents a unique combination of technological and supply chain challenges. These difficulties are associated with ensuring the safety of production, solving engineering, logistics and environmental problems, which makes this project one of the largest and most complex industrial projects in the world.

The field is characterized by high reservoir pressure up to 850 atmospheres. High quality oil -46 ° API, but with a high GOR, hydrogen sulfide and mercaptan content.

Kashagan was announced in the summer of 2000 following the results of drilling the first well Vostok-1 (East Kashagan-1). Its daily flow rate was 600 m³ of oil and 200 thousand m³ of gas. The second well (West-1) was drilled in West Kashagan in May 2001, 40 km from the first. It showed a daily flow rate of 540 cubic meters of oil and 215 thousand cubic meters of gas.

For the development and assessment of Kashagan, 2 artificial islands were built, 6 exploration and 6 appraisal wells were drilled (Vostok-1, Vostok-2, Vostok-3, Vostok-4, Vostok-5, West-1.

Due to the shallow waters and cold winters in the North Caspian, the use of traditional drilling and production technologies such as reinforced concrete structures or jack-up platforms installed on the seabed is not possible.

To provide protection from harsh winter conditions and ice movements, offshore structures are installed on artificial islands. Two types of islands are envisaged: small "drilling" islands without personnel and large "islands with technological complexes" (ETC) with maintenance personnel.

Hydrocarbons will be pumped through pipelines from the drilling islands to the ETC. The ETC islands will house process units for the recovery of the liquid phase (oil and water) from raw gas, gas injection units and power systems.

In Phase I, approximately half of the total gas produced will be injected back into the reservoir. The recovered fluids and crude gas will be piped to the shore at the Bolashak plant in the Atyrau region, where it is planned to prepare the oil to commercial quality. Some of the gas will be sent back to the offshore complex for use in power generation, while some of the gas will meet similar needs of the onshore complex.

There are a number of technical difficulties in the development strategy of Kashagan:

The Kashagan reservoir lies at a depth of about 4,200 meters below the seabed and has high pressure(initial reservoir pressure 770 bar). The reservoir is characterized by an increased content of sour gas.

The low level of salinity caused by the influx of fresh water from the Volga, combined with shallow water and temperatures down to -30C in winter, leads to the fact that the North Caspian is covered with ice for about five months a year. Ice movement and furrowing from ice movement on the seabed pose serious constraints to construction work.

The North Caspian is a very sensitive ecological zone and habitat for a variety of flora and fauna, including some rare species. Environmental responsibility is our top priority for NCOC. We work steadily and vigorously to prevent and minimize any environmental impact that may arise from our operations.

The North Caspian region is an area where the supply of equipment important for the project is associated with certain difficulties. Logistic difficulties are exacerbated by restrictions on access by water transport routes, such as the Volga-Don Canal and the Baltic Sea-Volga water transport system, which, due to heavy ice cover, are open for navigation only for about six months a year.

I would like to note the export strategy of this project. The existing plan for the export of post-field production provides for the use of existing pipeline and rail systems.

The western route of the CPC pipeline (pipeline from Atyrau to Novorossiysk along the Black Sea coast), the northern route from Atyrau to Samara (connecting to the Russian Transneft system) and the eastern route (Atyrau to Alashankou) provide connections to existing export transportation systems.

A possible southeastern route depends on the development of the Kazakhstan Caspian Transportation System (KCTS), which could pump oil from Eskene West, where the Bolashak plant is located, to the new Kuryk terminal. The oil can then be transported by tanker to a new terminal near Baku, where it would be pumped into the Baku-Tbilisi-Ceyhan (BTC) pipeline system or other pipelines to enter international markets.
All possible export routes are currently being explored.

This project takes into account safety and environmental protection. Since the formation of the first consortium in 1993, many environmental protection programs have been developed and implemented during onshore and offshore oilfield operations. For example, Agip KCO engaged local companies to carry out an environmental impact assessment (EIA) for its activities, including the construction of onshore and offshore facilities, trunk pipelines and onshore export pipelines. A program was initiated to fund scientific research in the field of biological diversity in the Caspian region. Twenty air quality monitoring stations were built in the Atyrau region. Soil research and monitoring of the state of the population of birds and seals are carried out annually. In 2008, a map of the environmentally sensitive areas of the North Caspian region was published, created, among other things, on the basis of data collected by the consortium.

There are also problems with sulfur utilization. The Kashagan field contains about 52 trillion cubic feet of associated gas, most of which will be re-injected at offshore facilities to improve oil recovery. In Phase 1 (Pilot Development Phase), not all associated gas will be re-injected into the reservoir at offshore facilities. Part of it will be sent to an onshore oil and gas processing unit, where the gas desulfurization process will take place, which will then be used as fuel gas to generate electricity for onshore and offshore operations, while part of it will be sold on the market as a commercial gas. Phase 1 plans to produce an average of 1.1 million tonnes of sulfur per year from sour gas purification.
Although the consortium plans to sell the entire volume of sulfur produced, it may become necessary to temporarily store the sulfur. Sulfur produced at the Bolashak plant will be stored in closed conditions, isolated from the environment. Liquid sulfur will be poured into sealed containers equipped with sensors. Sulfur will be converted to a pastel form prior to marketing to avoid the formation of sulfur dust during crushing.

In addition to a responsible approach to the conduct of production operations, program participants take on social and environmental obligations, the fulfillment of which will benefit the citizens of Kazakhstan in the long term. Fulfilling these obligations requires close cooperation with state and local authorities, with the local community and initiative groups.

In the period from 2006 to 2009. more than US $ 5.3 billion was spent on purchasing local goods and services. In 2009, payments for local goods and services accounted for 35% of the company's total expenses.

In 2009, during the period of maximum activity in the construction of facilities of the Pilot Development Stage, more than 40,000 people were employed in the project in Kazakhstan. More than 80% of the workers were citizens of Kazakhstan - an exceptional figure for projects of this scale.

Infrastructure projects and social significance are essential components of NCOC's corporate and social responsibility. According to the NCSPSA, a significant part of the investment in the development of the field goes to the construction of social infrastructure facilities in the field of education, health care, sports and culture. Funds are evenly distributed between Atyrau and Mangistau regions, where production operations are carried out on the SPSS.

Since 1998, 126 projects have been implemented in close cooperation with local authorities, 60 projects in the Atyrau region and 66 in the Mangistau region. A total of US $ 78 million was spent in the Atyrau region and US $ 113 million - in the Mangistau region.

In addition, under the 2009 Sponsorship and Philanthropy Program, NCOC and Agip KCO have supported more than 100 cultural, health, education and sports initiatives. Among them are advanced training of doctors and teachers, seminars on intercultural education and environmental literacy in schools, inviting leading Russian surgeons to operate on Atyrau children, buying musical instruments for the Aktau school and purchasing medical equipment and ambulances for a hospital in Tupkaragan.

Occupational health and safety play an important role. The participants in this project will carry out systematic risk management in order to continuously improve the health, safety and environment protection system and reach the level of world leaders in this indicator. All this is carried out in accordance with the requirements of the Production Sharing Agreement for the North Caspian Sea, Kazakhstani and international legislation, existing industry standards and corporate directives.

All participants of the SPSPS undertake:

Carry out their activities, ensuring the health and safety of all employees directly or indirectly involved in these activities, the environment in which their production operations are carried out, as well as the company's assets.

Manage the consortium's activities and related risks in accordance with the requirements of the North Caspian Production Sharing Agreement, Kazakh and international legislation, and apply the best existing industry standards in those matters that cannot be regulated by laws and regulations.

Promote the integration of HSE principles into the culture of the company, where all workers and service providers have a joint responsibility to implement these principles and lead by example.

Develop systems that allow for a systematic assessment of HSE risks at all stages of the company's activities and effectively control these risks.

Develop, conduct certification of the HSE management system and continuously inform the Agents, the Authorized Body, all interested parties about the state of the art in the field of HSE in order to continuously improve.

Select business partners based on their ability to meet their HSE obligations.

Implement systems and procedures to respond promptly and effectively to unplanned and undesirable events and check them regularly.

Raise the level of awareness of the personal responsibility of all employees of the company in the prevention of risks of accidents, damage to health and the environment.

Carry out joint work with state bodies of the Republic of Kazakhstan and all interested parties in order to develop regulations and standards aimed at increasing the level of safety of company employees and protecting the environment.

Apply a constructive approach in their activities based on dialogue with stakeholders and the public and aimed at achieving recognition of the company's activities by the local community through the implementation of social programs.

Sponsorship and Philanthropy projects aim to promote economic sustainability and welfare, support health care, education, culture and cultural heritage, sports, and help eligible low-income people, and align with NCOC's strategic goals of sustainable development. Agip KCO is responsible for the implementation of the sponsorship and charity program.

In particular, projects involve their own contributions from the participants themselves, and must also demonstrate to the public their long-term sustainability. The support of political or religious organizations is excluded, projects cannot create unfair conditions for market competition, negatively affect environmental stability and / or natural ecosystems. Projects are usually developed by local authorities, NGOs or community representatives, but can also be initiated by NCOC or its Agents as proactive measures to support local communities.

Bibliography:

State program for the development of the Kazakh sector of the Caspian Sea

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Development plan for the Karakudyk deposit. Business plan for the development of the Egoryevskoye building stone deposit Plan for the development of the deposit

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