Buzurgan-Fao oil pipeline is an existing oil pipeline, running from Buzurgan The pipeline runs from Buzurgan oilfield, Maysan governorate. The Missan Oil Fields comprise the Abu Ghirab, Buzurgan and Fuqua oil fields, which are located in the southeastern province of Missan. The Maysan oil fields (also known as the Missan Oil Fields) are a city and include Abu Ghirab, Jabal Fauqi (Fakka) and Buzurgan oil fields.

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Net Present Value Summary. Reservoir and Fluid Properties. Missan Oilfields, Iraq Gross Reserves.

Missan Oil Price Scenario. Missan Fields Location Map. Geological Location of Missan Fields. Stratigraphy and Petroleum System. Missan Field Seismic Database.

Abu Ghirab Depth Structure Map. Buzurgan Depth Structure Map. Fauqi Depth Structure Map. Reservoir Pressure for the Missan Fields. Abu Ghirab Buzurrgan Production History.

Buzurgan Fieldd Production History. Fauqi Oil Production History. Technical Qualifications of Person Responsible for Audit. Director of Reserve Management Office.

No 25 Chaoyangmenbei Buuzrgan. Missan is located km southeast of Baghdad, Iraq Figure 0. First production from the Abu Ghirab and Buzurgan fields commenced in ; with start-up of the Fauqi field occurring in early The production from all the Missan fields was shut down between October, and Bizurgan, during the Iran-Iraq War; production was again shut-in for a period in during the Gulf War. The contract formally came into force on 20 th December, Implementation will be achieved in two periods: The rehabilitation of surface facilities, drilling of new wells and reservoir surveillance program shall be completed in the Rehabilitation Period and a Minimum Work Obligation is also required.

Work Obligations for the Rehabilitation Plan defined in the contract, which are summarized below.

The first is appraisal work, including 3D seismic acquisition, processing and interpretation, appraisal well drilling, and geological and engineering studies. The third is the design and construction of an oil export pipeline from the oilfields to Fao Port. DuringCNOOC has commenced operations under the Rehabilitation Plan but progress has been slower than expected with only 7 new wells drilled and no workovers or stimulation operations completed. The most significant differences between the original and the updated versions of the Rehabilitation Buzuryan are the withdrawal of 9 planned injector wells, resulting in all new wells planned being producers, and the reduction of planned well interventions from to Hence, the production rate needs to be doubled in if the initial target rates are to be achieved.

In order to meet these production targets, CNOOC expects to have a total of 19 drilling rigs and 2 workover rigs operating during Three rigs were used for the wells drilled in and are buzjrgan only ones currently drilling. Four additional rigs are on stand-by and it is expected fielc they will start drilling in Q1 The remaining rigs are expected to start operating over Q2 and Q3 Although, if executed, GCA considers the production targets could be achieved providing that the new well productivity is as expected.

GCA has classified as Reserves those hydrocarbon volumes that would be economically recoverable as a result of implementing the 3-year Rehabilitation Plan. Therefore, the reserves estimates included in this report are limited to volumes produced from operations planned under the 3-year Rehabilitation Plan. In line with the foregoing, the statement of reserves, presented herein, is based on a program that is expected to be superseded by the redevelopment activities proposed under the ERP to be submitted by 20 th December, As such, the volumes actually recovered under the enlarged plan are expected to be significantly greater than those presented; however, should buzugran ERP not be approved, it is possible that the CNOOC would be seen as in default of the contract buzurgsn there could be an early termination and a consequential reduction fielld reserves.

Under the terms of buzhrgan TSC, the Contractor is entitled to use any quantity of Associated Gas from the oil reservoirs necessary for Petroleum Operations and for power generation.


Thus, the contractor has no entitlement to any Gas Reserves. It was recognized however that a complete reconciliation of all matters was beyond the scope of this study. This audit examination was based on information and data provided by CNOOC to GCA on or before 31 st December,and included such tests, procedures and adjustments as were considered necessary.

All questions that arose during the course of the audit process were resolved to our satisfaction. The results presented in this report are based upon information and data made available to GCA on or before 31 st December, The economic tests for the reserve volumes as at 31 st December, were based on a prior twelve-month first-day-of-the-month average reference price for UK North Sea Brent crude of U.

No price escalation has been included. Recent historical operating expense data were utilized as the basis for operating cost projections. GCA has found that CNOOC has projected sufficient capital investments and operating expenses to produce economically the projected volumes recoverable filed the development activities planned under the Rehabilitation Period of the contract. GCA concludes that the methodologies employed by CNOOC in the derivation of the reserves estimates are appropriate and that the quality of the data relied upon, the depth and thoroughness of the reserves estimation process is adequate.

It should be understood that any evaluation, particularly one involving future improvement developments, may be subject to significant variations over short periods of time, as new information becomes available and perceptions change. In this regard, it is noted again that the reserves estimates included in this report are limited to volumes produced from operations planned under the 3-year Rehabilitation Plan and as such are expected to be superseded by a revised assessment when the redevelopment activities proposed under the ERP has been approved by MOC and implementation of the plan initiated.

As such, the volumes actually recovered under the enlarged plan are expected to be significantly greater than those presented herein; however, should the ERP not be approved, it is possible that the CNOOC would be seen as in default of the contract and there could be an early termination and a consequential reduction in reserves.

A glossary of abbreviations and key industry standard terms, some of which may be used in this report, is attached as Appendix II.

The total proved reserves covered by this report is about 1. Only volumes within the boundaries of the TSC have been considered. It should be noted that these estimates only consider the Rehabilitation Phase and do not include volumes to be produced from the Enhanced Redevelopment Plan, which is currently still undefined.

Cumulative production, to end December,is also included in the Low, Best and High estimates reported below. Cumulative production statistics were based on history production data provided.

Totals may not compute exactly due to rounding errors. The economic cut offs were applied following Economic Limit Tests ELTs using costs and prices which are un-escalated throughout the period of calculation.

Individual field volumes have been back allocated proportionally based on individual production forecasts and are only approximate. Gross reserves include volumes attributable to third parties government and other working interest partners. The reference NPVs reported here do not represent an opinion as to the market value of a property or any interest in it. The NPVs were calculated on the basis of SEC guidelines under which the economic cut-offs were applied using constant costs and prices.

The oil prices used for these computations were the un-weighted month arithmetic average of the first-day-of-the month price for each month within the month period January to December, It should be noted that the NPVs of future revenue potential of a petroleum property, such as those discussed in this report, do not represent an opinion as to the market value of that property, nor any interest in it.

In assessing a likely market value, it would be necessary to take into account a number of additional factors including: GCA has explicitly not taken such factors into account in deriving the reference NPVs presented herein. This structural and topographic front defines the arcs and embayments in the folded belt from SE to NW: These buried anticlines are containing the richest oil traps in frontal part of the ZSFB.


The border between the regions is defined by the NW-SE trending gentle anticlines which are located along the southwestern margin of the Dezful Embayment. Two major structural trends control oil and gas reservoirs in this area. The structural trends of the Missan are much coincidence with those in the Dezful Embayment.

That makes it more inclining to be part of the Dezful Embayment, geologically, than the Mesopotamian Foreland Basin. Existing study shows that the influence of the tectonic events on petroleum entrapment is particularly important in the Dezful Embayment of the ZSFB. But this area is still under-explored, even after about years of production.

As the most obvious accumulations have been located, many in structural traps, stratigraphic models are of increasing exploration importance. The Kazhdumi sequence is composed of alternating dark gray marls and clayey limestones.

Iraq: CNOOC close to signing Missan oil field deal

Together with bitumens, a part of this sulfur was delivered to pools of the main productive fields and oils of these fields are enriched in sulfur. Available data shows that the associated gas from Buzurgan field contains H 2 S up to 2. A study shows a monotonous and thick to m sequence of grey marls were deposited. Other source rocks to the charge of the Missan, are potentially from Cretaceous sources, such as Aptian Shuaiba, Albian Zubair and Sulaiy, and from Jurassic, but their contribution to the charge of the reservoirs is negligible.

Some models indicate the expulsion maturation commenced as early as 90 Ma Late Cretaceous with peak expulsion about 27 Ma Oligocene. Most models show peak generation to be very recent 15 Ma or less in the Mid Miocene Neogene coincident with the Zagros collision and the thick accumulation of orogenic clastics in the Zagros foredeep. One modeling shows that Kazhdumi and Pabdeh reached the onset of oil expulsion, 1 to10 Ma, after the beginning of the Zagros folding.

Migrations took place almost vertically and were facilitated by intense fracturing in high-relief anticlines. Gurpi and Pabdeh are considered not only contributed significant amounts of hydrocarbon to the Asmari Formation but also act as a good seal for Bangestan Mishrif. In the time period of Cenomanian to Turonian of early Late Cretaceous, the deposition of the Mishrif was widely spread with shallow-marine platform carbonates. The so-called paleohighs, or ridges, had strongly affected the distribution of Mishrif facies, such as the Samarra-Dujaila-Amarah ridge where the Missan located.

A study based on some key well data scattered in the southern Mesopotamian Basin in Iraq shows the Mishrif play includes rudist-bearing shoals and biostromal carbonate reservoirs with thickness may reach m and the thickest area is nearby the Missan.

Buzurgan oilfield, Wāsiţ, Iraq

Mishrif reservoir property is quite good with porosity. The Asmari Formation deposited during the Oligocene-Miocene. Studies indicate the Asmari Formation is a thick sequence buzurgah shallow water carbonate representing sedimentation on a carbonate ramp. The Asmari reservoir is one of the best known carbonate reservoirs in the world. Lithologically, the Asmari Formation consists of limestone, dolomitic limestone, dolomite and marly limestone.

Some anhydrite and lithic and limy sandstones also occur within the Asmari Formation. The formation is generally characterized by a large-scale trend of upward-decreasing accommodation. Basal strata were deposited under relatively open-marine, high-energy conditions, whereas the Middle to Upper Asmari succession was deposited in relatively protected settings with more frequent evidence of exposure and evaporitic conditions.