Plan for the development of the Karakudyk deposit. Development plan for the strategically important Kashagan field on the shelf of the Caspian Sea - abstract Field development plan

The main graphic document in the calculation of reserves is the calculation plan. Estimated plans (Fig. 3) are compiled on the basis of a structural map along the top of productive reservoirs or the nearest benchmark located no more than 10 m above or below the top of the reservoir. External and internal 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 category are colored in a certain color:

Rice. 3. An example of a deposit calculation plan.

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

Wells: 4 - producing, 5 - exploratory, 6 - mothballed, 7 - liquidated, 8 - not flowing; 9 - isohypses of the reservoir surface, m;

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

Numerals at the wells: numerator - well number, denominator - absolute elevation of the reservoir top, m.

All wells drilled as of the date of calculation of reserves are also applied to the calculation plan (with an exact indication of the position of the mouths, the points of intersection of the roof of the corresponding productive formation by them):

Exploration;

Mining;

Mothballed in anticipation of the organization of fishing;

Pressure and observation;

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

Under trial;

Untested, with specification oil-, gas- and water-saturation of formations - collectors according to the interpretation of materials of geophysical surveys of wells;

Liquidated, indicating the reasons for liquidation;

Revealed a layer composed of impermeable rocks.

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

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

When recalculating reserves, the boundaries of the categories of reserves approved during the previous calculation should be plotted on the calculation plans, as well as the wells drilled after the previous calculation of reserves should be highlighted.

Calculation of reserves of oil, gas, condensate and 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 layer of the deposit and the field as a whole with a mandatory assessment of the prospects of the entire field.

Stocks of components contained in oil and gas, which are of industrial importance, are calculated within the limits of reserves calculation oil and gas.

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

Stocks 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.

The average values of the parameters and the results of the calculation of reserves are given in tabular form.

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The organization was founded in December 2005. The project operator is KarakudukMunay 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 18.09.1995. The term of the contract is 25 years. The Karakuduk field is located in the Mangistau region, 360 km from the city of Aktau. Residual recoverable hydrocarbon reserves - 11 million tons. Production in 2011 - 1.4 million tons of oil (LUKOIL's share - 0.7 million tons) and 150 million cubic meters of gas (LUKOIL's share - 75 million cubic meters). Investments since the beginning of the project (since 2006) - more than 400 million dollars in the share of LUKOIL. Total population employees - about 500 people, of which citizens of the Republic of Kazakhstan - 97%. LUKOIL plans to invest up to 0.1 billion dollars in the development of the project until 2020.

Proven oil and gas reserves (in the share of LUKOIL Overseas)
	million barrels
	bcm3
Oil and gas	million barrels n. e.
Commercial production for the year (in the share of LUKOIL Overseas)
	million barrels

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

GENERAL INFORMATION ABOUT THE DEPOSIT

Geographically, the Karakuduk deposit is located in the southwestern part of the Ustyurt plateau. Administratively it belongs to the Mangystau 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. Beyneu station is located 160 km from the deposit. The distance to the regional center Aktau is 365 km.

Orographically, the study area is a desert plain. The absolute elevations of the relief surface range from +180 m to +200 m. The study area is characterized by a sharply continental climate with hot, dry summers and cold winters. The hottest month of summer 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 area 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). Summer is dominated by NW winds directions, in winter - N-E. The snow cover in the work area is uneven. The thickness in the most submerged low-lying areas reaches 1-5 m.

The flora and fauna of the region is poor and is represented by species typical of semi-desert zones. Rare herbaceous and shrubby vegetation is characteristic: camel thorn, wormwood, saltwort. Animal world represented by rodents, reptiles (turtles, lizards, snakes) and arachnids.

There are no natural water sources in the work area. At present, the sources of water supply for the field drinking water, for technical needs and firefighting needs is the Volga water from the main water pipeline "Astrakhan-Mangyshlak", as well as special water intake wells up to 1100 m deep for Albsenomanian deposits.

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

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 deposits with a maximum thickness of 3662 m (well 20), ranging from Triassic to Neogene-Quaternary inclusive, was discovered.

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

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

Jurassic system - J. With stratigraphic and angular unconformity, the underlying rocks of the Triassic are overlain by a sequence of Jurassic deposits.

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

Lower section - J 1. The Lower Jurassic section is lithologically complicated by intercalation of sandstones, siltstones, clays, and mudstones. The sandstone is light gray with a greenish tinge, fine-grained, poorly sorted, strongly cemented. Clays and siltstones are dark gray with a greenish tint. Argillites are dark gray with ORO inclusions. Regionally, the Yu-XIII horizon is confined to the Lower Jurassic deposits. The thickness of the Lower Jurassic deposits varies between 120-127m.

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

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

Bajocian Stage - J 2 c. Sandstones are gray and light gray, fine-grained, strongly cemented, non-calcareous, micaceous. Siltstones are light gray, fine-grained, micaceous, clayey, with inclusions of charred plant remains. Clays are dark gray, black, dense in places. The productive horizons Yu-VI-Yu-X are confined to deposits of this age. The thickness is about 462m.

Bathian Stage - 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. Productive horizons Yu-III- Yu-V are confined to the sediments of the Bathonian stage. The thickness varies from 114.8m to 160.7m.

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

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

Oxfordian-Volgian stage - J 3 ox-v. The deposits 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, have a greenish tint.

The section of the Volgian time is a stratum of argillaceous limestones with interlayers of dolomites, marls and clays. Limestones are often fissured and porous, massive, sandy, clayey, with uneven fracture and matte sheen. The clays are silty, gray, calcareous, often with inclusions of faunal remains. Dolomites are gray, dark gray, cryptocrystalline, clayey in places, with uneven fracture and matte luster. 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 division of the section into tiers was made on the basis of logging data and comparison with neighboring areas.

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

Neocomian superstage - K 1 ps. The underlying Volgian deposits conformably overlie the thickness of the Neocomian interval, which unites three stages: Valanginian, Hauterivian, Barremian.

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

At the level of the Hauterivian interval, the section is mainly represented by clays, marls, and only at the top is a horizon of sands. The Barrem deposits are distinguished in the section by the variegated color of the rocks and are lithologically composed of clays with interbeds of sandstones and siltstones. Throughout the section of the Neocomian age, there are members of silty-sandy rocks. 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, and siltstones, and in the upper part, there is a uniform alternation of clayey 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 the underlying ones. 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. Sediments of the Cenomanian stage 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 - K 2 t-cn. In the lower part of the described complex, the Turonian stage is distinguished, composed of clays, sandstones, limestones, chalk-like marls, which are a good benchmark.

Above the section, there are deposits of the Santonian, Campanian, Maastrichtian stages, united in the Senonian superstage, represented in lithological terms by a thick layer 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 silty clays. The thickness varies from 498m to 533m.

Neogene-Quaternary systems - N-Q. Neogene-Quaternary deposits are composed mainly of carbonate-argillaceous rocks of light gray, green and brown color 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 deposit 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

Based on the materials of seismic surveys MOGT-3D (2007) conducted by OJSC Bashneftegeofizika, the Karakuduk structure along the reflecting horizon III represents a brachianticline fold of sublatitudinal strike with dimensions of 9x6.5 km along a closed isohypse minus 2195m, with an amplitude of 40m. The angles of incidence of the wings increase with depth: in the Turonet - fractions of a degree, in the Lower Cretaceous -1-2˚. The structure along reflector V is an anticline broken by numerous faults, possibly some of which are non-tectonic. All major faults described below are traced along this reflector. The N-striking fold consists of two arches, contoured by isohypse minus 3440 m, identified in the area of wells 260-283-266-172-163-262 and 216-218-215. According to the isohypse minus 3480m, the fold has dimensions of 7.4x4.9km and an amplitude of 40m.

The uplift on the structural maps along the Jurassic productive horizons has an almost isometric shape, complicated by a series of faults that divide the structure into several blocks. The most basic disturbance is the F 1 disturbance in the east, which is 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 displacement amplitude from south to north from 10 to 35 m. The fault F 1 is inclined and shifts 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.

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

Description of work

The oil field has a fairly long life cycle. Several decades may pass from the discovery of an oil deposit to the production of the first oil. The entire process of developing an oil field can be divided into five main stages.

SEARCH AND EXPLORATION

1 Discovery of oil fields

Oil and gas are found in rocks ah - reservoirs, as a rule, at a considerable depth
Seismic studies are carried out to detect oil deposits in the rock mass. Research allows you to get an image of the deep layers of rocks, in which experienced specialists identify potentially productive structures
To make sure that there is oil in the identified mountain structures, exploration wells are drilled.

2 Estimation of oil reserves

When the discovery of a deposit is confirmed, its geological model is built, which is a set of all available data. Special software allows you to visualize this data in a 3D image. A digital geological model of the field is needed to:

Estimate initial and recoverable oil (and gas) reserves
Develop an optimal field development project (number and location of wells, oil production levels, etc.)

For more qualitative assessment reserves are drilled appraisal wells. And drilling exploration wells helps to clarify the size and structure of the deposit.

At this stage, it is economic evaluation the feasibility of developing the field based on the forecast levels of oil production and the expected costs of its development. If the expected economic indicators meet the criteria oil company, then she proceeds to develop it.

OIL AND GAS

3 Preparing for the development of the field

For the purpose of optimal development of the oil field, a Development Project is being developed ( Technology system development) and the Field Development Project. The projects include:

Required amount and location of wells
The best way to develop a field
Types and cost necessary equipment and facilities
Oil collection and treatment system
Security measures environment

The development of drilling technologies and the introduction of directional wells into practice make it possible to arrange the wellheads in the so-called "bushs". On one bush can be located from two to two dozen wells. The cluster arrangement of wells allows to reduce the impact on the environment and optimize the cost of field development.

4 Oil and gas

The period for which oil reserves can be extracted is 15 - 30 years, and in some cases it can reach 50 years or more (for giant deposits).

The field development period consists of several stages:

Growing production stage
Stabilization of production at the maximum level (plateau)
Falling prey stage
Final period

The development of oil production technologies, the implementation of geological and technical measures (GTO), the use of enhanced oil recovery (EOR) methods can significantly extend the cost-effective period of field development.

5 liquidation

After the level of oil production becomes lower than profitable, the development of the field is stopped, and the license is returned to state bodies.

Ministry Education and Science of the Republic of Kazakhstan

Faculty of Finance and Economics

Department of Economics and Management

D
discipline: Oil and gas project evaluation

SRS №1

Topic: Plan for the development of the strategically important Kashagan field on the shelf of the Caspian Sea

Performed:

3rd year student "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 at an average of 3.3% per year, while world demand for oil as the main source of hydrocarbons is growing at an average of 1% per year. The lagging of hydrocarbon consumption behind 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 aggravation of the problems of hydrocarbon supply is expected.

The territorial proximity of such large and dynamically developing countries as Russia and China opens up broad prospects for the export of Kazakh hydrocarbons. To ensure entry into their market, it is necessary to develop and improve the system of main pipelines.

Estimates by international experts show that if current trends continue, all the world's proven oil reserves will last only 40-50 years. The addition of KSCM oil 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 born in the Mangistau region, the Kashagan field is one of the world's largest discoveries in the last 40 years. Refers to the Caspian oil and gas province.

The Kashagan field is located in the Kazakh sector of the Caspian Sea and covers a surface 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 Northern Caspian, was discovered by Soviet geophysicists during 1988-1991 by prospecting seismic work. on the sea continuation of the Karaton-Tengiz uplift zone.

Subsequently, it was confirmed by studies of Western geophysical companies working on behalf of the government of Kazakhstan. The Kashagan, Korogly and Nubar massifs originally identified in its composition in the period 1995-1999. received the names Kashagan East, West and South-West, respectively.

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

Kashagan West borders on Kashagan East along a submeridional structural ledge, which is possibly associated with tectonic disturbance. 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 away (to the south) from the main massif. The uplift along the closed stratoisohypse - 5400 m has dimensions of 97 km, area - 47 km², amplitude - 500 m.

Oil reserves of Kashagan fluctuate within a wide range of 1.5 - 10.5 billion tons. Of these, from 1.1 to 8 billion tons fall on the Eastern, up to 2.5 billion tons on the Western and 150 million tons on the South-West.

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

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

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

Appointed as the project operator in 2001 by partners: Eni, and created the Agip KCO company. The project participants are working on the creation of a joint 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) have agreed to postpone the start of oil production from 2011 to the end of 2012.

Oil production at Kashagan should be up to 50 million tons per year by the end of the next decade. Oil production at Kashagan, according to ENI, 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 enhance oil recovery and reduce H3S content, the consortium is preparing to use several onshore and offshore units in Karabatan for injection natural gas into a productive reservoir, an oil pipeline and a gas pipeline with Karabatan will be built.

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

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

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

For the development and evaluation 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, Zapad-1.

Due to shallow water and cold winters in the Northern 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 shifts, 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 service personnel.

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

In Stage I, approximately half of all gas produced will be injected back into the reservoir. The extracted fluids and sour gas will be pipelined ashore to the Bolashak OPF in the Atyrau region, where it is planned to treat the oil to commercial quality. Some volumes of 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 a high pressure (initial formation pressure of 770 bar). The collector is characterized by an increased content of sour gas.

The low level of mineralization caused by the influx of fresh water from the Volga, combined with shallow water and winter temperatures down to -30C, causes the Northern Caspian to be covered with ice for about five months of the year. Ice shifts and the formation of furrows from the movement of ice on the seabed are serious restrictions on construction work.

The Northern Caspian is a very sensitive ecological zone and habitat for a variety of flora and fauna, including some rare species. NCOC considers environmental responsibility a top priority. We work relentlessly and diligently to prevent and minimize any environmental impacts 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. Logistical difficulties are exacerbated by access restrictions on water transport routes, such as the Volga-Don Canal and the Baltic Sea-Volga water transport system, which, due to thick ice cover, are open for navigation for about six months a year.

I would like to note the export strategy this project. The existing plan for the export of post-commissioning products involves the use of existing pipeline systems and railroads.

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

A possible southeast route depends on the development of the Kazakhstan Caspian Transportation System (KCTS), which could transport oil from Eskene West, where the Bolashak plant is located, to the new Kuryk terminal. The oil could 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 reach 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 the onshore and offshore oilfield operations. For example, Agip KCO engaged local companies to carry out environmental impact assessments (EIAs) of its activities, including the construction of onshore and offshore facilities, trunk pipelines and onshore export pipelines. A program was initiated to finance scientific research in the field of biological diversity of 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 environmentally sensitive areas of the North Caspian region was published, which was created, among other things, on the basis of data collected by the consortium.

There are also problems with the disposal of sulfur. The Kashagan field contains about 52 trillion cubic feet of associated gas, most of which will be reinjected into the reservoir at offshore facilities to increase the oil recovery factor. In Stage 1 (Pilot Development), not all associated gas will be re-injected into the reservoir at offshore facilities. Part of it will be sent to an onshore complex oil and gas treatment plant, where the gas will be desulfurized, 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 commercial gas. gas. Stage 1 is expected to produce an average of 1.1 million tonnes of sulfur per year from sour gas treatment.
While the consortium plans to sell all of the sulfur produced, it may be necessary to temporarily store the sulfur. Sulfur produced at the Bolashak plant will be stored under closed conditions, isolated from the environment. Liquid sulfur will be poured into sealed containers equipped with sensors. The sulfur will be converted to pastelled form prior to sale, thus avoiding the formation of sulfur dust during crushing.

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

Between 2006 and 2009 more than US$5.3 billion was spent on local goods and services. In 2009, 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 Stage facilities pilot development 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 magnitude.

Infrastructure and social projects are important components of NCOC's corporate and social responsibility. According to the SRPSK, a significant part of the capital investments in the development of the field goes to the construction of social infrastructure facilities in education, healthcare, sports and culture. Funds are evenly distributed between Atyrau and Mangystau regions, where production operations are carried out under the SRPSK.

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 Atyrau Oblast and US$113 million in Mangistau Oblast.

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

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

All participants of the SRPSK undertake:

Carry out their activities, ensuring the protection of 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 company assets.

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

Promote the implementation of HSE principles in the company culture, where all employees and service providers will be jointly responsible for the implementation of these principles, and lead by example.

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

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

To choose business partners based on their ability to meet their HSE obligations.

Implement systems and procedures to respond promptly and effectively to unplanned and unwanted events and regularly review them.

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.

Conduct joint work from government bodies Republic of Kazakhstan and all interested parties in order to develop regulations and standards aimed at improving the safety of company employees and protecting the environment.

Apply a constructive approach in its 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 wealth, support health care, education, culture and cultural heritage, sports, and help eligible disadvantaged individuals, and be in line with NCOC's strategic goals for sustainable development. The implementation of the sponsorship and charity program is entrusted to Agip KCO.

In particular, projects involve their own contributions by the participants themselves, and must also demonstrate to the public their long-term sustainability. 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 typically developed by local governments, NGOs, or community representatives, but may also be initiated by NCOC or its Agents as a proactive measure in support of local communities.

Bibliography:

State Program for the Development of the Kazakh Sector of the Caspian Sea

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