Petroleum exploration_developement_production_process

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This document summarizes the key stages of petroleum exploration, development, and production. It discusses that exploration involves reconnaissance, prospecting, drilling wells to find discoveries or determine dry holes. If a discovery is made, further appraisal and development occurs. This includes additional seismic surveys and wells to accurately determine the reserve size and optimal number of production wells. Production levels are then set based on reservoir properties and economics to maximize recovery over the field life. The document stresses the importance of not overproducing wells to avoid damaging the reservoir or leaving behind untapped reserves.

Business Technology

PETROLEUM
EXPLORATION,
DEVELOPMENT AND
PRODUCTION PROCESS
MUHAMMAD IMADUDDIN
Managing Director, BAPEX
BUET, 30 APRIL 2008

THE STAGES OF EXPLORATION AND
DEVELOPMENT
RECONNAISANCE DETAILING
PROSPECT STRUCTURE
DRILLING WELL RESULT
DISCOVERY OR DRY REVIEW
APPRAISAL DEVELOPMENT
PRODUCTION

CONDITIONS OF FINDING PETROLEUM
IS THERE A TRAP TO HOLD PETROLEUM
Find a geological feature that can act as an accumulator of oil/gas
IS THE TRAP SEALED
Determine that the accumulator is sealed; oil/ gas cannot escape
IS THERE A MIGRATION PATH
A path must exist to allow flow of oil/gas to the trap
IS THERE SOURCE MATERIAL OF PETROLEUM
Area must had the material and environment to cook oil/gas

WHERE TO FIND A TRAP
EXPLORATION IS EXPENSIVE, SO
WHERE DO WE SEARCH
WHAT ARE THE PRIORITIES
WHY SOME AREAS ARE LESS EXPLORED
FOCUS ON MORE PROSPECTIVE AREAS
LOOK FOR LESS RISKY PROSPECT
COMPREHENSIVE SURVEY NARROWS DOWN AREA
FOR EXTENSIVE SURVEY

SURFACE GEOLOGY : THE INITIAL GUIDE
GRAVITY MAP: THE FIRST INDICATION

SEISMIC NETWORK
THE FINAL IDENTIFICATION

TYPE OF TRAPS
TRAPS COULD BE
STRUCTURAL:
Anticline easy to locate with very low risk
Fault bound easy to locate with fair risk
STRATIGRAPHIC:
Pinchouts tougher to locate with high risk
Channels tougher to locate with high risk
MORPHOLOGICAL
Buried hill
Reef

SEISMIC DATA SHOWING STRUCTURAL
VARIATION

DRILLING TO CONFIRM
Only when a structure is rated as prospective
in terms of trap, seal, migration and source,
it is drilled. A chance of success (COS/POS)
of 20 to 35 % is considered risk worthy.
Only 1 in 3 to 5 exploration wells find oil/ gas
Drilling is expensive, risky and tough.
Coring, logging, testing are part of drilling ops.

HOW MUCH IS THERE
After a well is drilled, it is logged i.e. parametric
measurements are taken using electric, nuclear and
sonic methods. Porosity, permeability, gas/ water
saturation, pressure, salinity are calculated.
Indicative zones are then perforated to test the flow of
gas/oil. Testing certifies a well as discovery or dry.
Discovery will lead to estimation of likely volume of
oil/ gas in the structure.
Initial estimation determines whether appraisal
survey and wells are required.

APPRAISAL AND DEVELOPMENT
DISCOVERY IS APPRAISED BY ADDITIONAL SEISMIC 2D/ 3D
PRODUCTIVE ZONES ARE MAPPED FOR MORE ACCURATE EXTENT
AND THICKNESS
MORE WELLS ARE DRILLED TO CONFIRM THE APPARISAL
RESERVE CALCULATED MORE ACCURATELY
PRODUCTION LEVEL DETERMINED
PRODUCTION WELLS ARE DRILLED FOR OPTIMISED PRODUCTION

HOW MANY WELLS IN A FIELD
Once the reserve volume is determined number of
wells that can be drilled is estimated.
Volume of reserve, distribution of reservoir, type of
depletion mechanism, economic considerations are
guiding factors.
Reservoirs may be continuous or discrete, depletion
zone per well may vary, field life vis a vis investment
required are major variables.

HOW MUCH PER WELL
Production volume per day/ year from each field is based
on the field producibility taking in to consideration field
life cycle and economic investment.
Each well is designed to produce an optimal volume
based on the reservoir condition: porosity, permeability,
petrology, saturation etc.
Over production ignoring rock/ reservoir property will
result in reservoir damage, loss of productive sand,
water coning, sand infiltration etc.

HOW MUCH PER WELL
Wells may have theoretical capability to produce more
than its optimal flow; but it is undesirable to over produce
wells to meet demand.
Over production sustained for long period will cause loss
of reservoir, leaving isolated zones that can not be
produced; or deplete the field without recovering
maximum reserve.
Bakhrabad and Sangu are two significant example.

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This research paper is focused to estimate the current production rate of the wells and to predict field remaining reserves. The remaining reserve depends on the production points that selected to represent the real well behavior, the way of dealing with the production data, and the human errors that might happen during the life of the field. Reserves estimating methods are usually categorized into three families analogy, volumetric, and performance techniques. Reserve Estimators should utilize the particular methods, and the number of methods, which in their professional judgment are most appropriate given i the geographic location, formation characteristics and nature of the property or group of properties with respect to which reserves are being estimated ii the amount and quality of available data and iii the significance of such property or group of properties in relation to the oil and gas properties with respect to which reserves are being estimated. In this research paper, the calculation of collecting data and sample by volumetric method are suggested to estimate the oil and gas production rate with time by using the geological configuration and the historical production data from CD 3700 3800 sand in Mann Oil Field. San Win "Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann Oil Field" Published in International Journal of Trend in Scientific Research and Development (ijtsrd), ISSN: 2456-6470, Volume-3 | Issue-5 , August 2019, URL: https://www.ijtsrd.com/papers/ijtsrd27945.pdfPaper URL: https://www.ijtsrd.com/engineering/petroleum-engineering/27945/reserve-estimation-of-initial-oil-and-gas-by-using-volumetric-method-in-mann-oil-field/san-win

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Oil and gas engineering involves the production of hydrocarbons from subsurface reservoirs. There are four main types: offshore, subsea, petroleum, and earth science engineering. The life cycle of an oil field consists of five stages: exploration, appraisal, development, production, and abandonment. Oil refineries process crude oil through various units to produce useful products like gasoline and diesel.

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The document summarizes the significant production improvement of an ultra-low permeability granitic reservoir in Egypt utilizing channel fracturing. Key points: 1) The target formation has very low natural fracture permeability of 0.1-0.5 md, requiring channel fracturing to access oil. 2) Well SID-18 encountered an unconventional granitic formation with challenging logging responses. Analysis found the lithology consists of granite, microgranite, and metagranite fragments. 3) Testing found the formation has an ultra-low permeability. Channel fracturing was utilized to successfully commercialize this challenging asset.

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Unconventional reservoir

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This document discusses unconventional reservoirs and shale gas. It begins with defining unconventional resources as hydrocarbon reservoirs with low permeability and porosity that are difficult to produce. Shale gas is then introduced as natural gas trapped in shale formations. The document outlines a roadmap for identifying and developing shale plays, including geological, geophysical, geochemical, and geomechanical approaches. Key factors like total organic carbon content, thermal maturity, and brittleness are examined. The concept of a "sweet spot" is introduced as the most prospective volumes within a shale play, characterized by properties like thickness and permeability. The document concludes with thanking the audience.

Graduation Project Book 2020

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This document provides an overview of a graduation project studying the SIMIAN field. It will integrate petroleum geology and exploration, drilling engineering, well logging, reservoir engineering, well testing, and production engineering. The study will include constructing structure contour maps, isopach maps, and calculating the original gas in place. It will also include determining the number of casing strings needed, designing the cement program, predicting drilling problems, and calculating the total drilling cost. Other aspects covered are making qualitative and quantitative log interpretations, identifying the reservoir driving mechanism, determining boundaries and properties from well testing, and selecting the optimum tubing size and gas processing method.

C05740912

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1) The document analyzes oil-water layer recognition and distribution of PI reservoirs in the G region based on core data, oil testing, and well logging. 2) An oil-water layer logging interpretation chart is established using resistivity logs to identify 5 types of vertical oil-water distributions in single wells and the overall horizontal zoning of distributions across the region. 3) The distributions are complex due to structural, sedimentary, and diagenetic factors but generally include pure oil, oil-water, and pure water layers that vary based on position within anticlines, synclines, and slopes.

TPE DRILLING.pptx

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This document discusses sampling procedures and considerations for reservoir fluids. It begins with an overview of why fluid sampling is important for analysis and production design. It then provides guidelines for establishing a sampling program, including selecting sampling sites, determining required measurements, and setting up the sampling plan. Special topics are covered such as sampling crude oil emulsions, waxy/asphaltenic fluids, and on-site measurements. Throughout, it emphasizes the need for representative samples and outlines best practices for fluid sampling.

Gas Production Technology

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Flow-Assurance Challenges in Gas-Storage Schemes in Depleted Reservoirs This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper SPE 146239, "Flow-Assurance Challenges in Gas-Storage Schemes in Depleted Reservoirs," by Alireza Kazemi, SPE, and Bahman Tohidi, SPE, Hydrafact Ltd., and Emile Bakala Nyounary, Heriot-Watt University, prepared for the 2011 SPE Offshore Europe Oil and Gas Conference and Exhibition, Aberdeen, 6–8 September.

SPE 160891 Tar Characterization for Optimum Reservoir .docx

rafbolet0

SPE 160891 Tar Characterization for Optimum Reservoir Management Strategy Muhammad Al-Harthi, Mohammed Al-Ali, Ronny Gunarto/ Saudi Aramco Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Saudi Arabia Section Technical Symposium and Exhibition held in Al-Khobar, Saudi Arabia, 8–11 April 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at the SPE meetings are subject to publication review by Editorial Committee of Society of Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of where and whom the paper was presented. Write Librarian, SPE, P.O. Box 833836, Richardson, TX 75083-3836, U.S.A., fax 01-972-952-9435. Abstract Tar mats are extra-heavy bitumen that occur between aquifers and overlaying oil columns. They seal either partially or completely an oil reservoir from its aquifer and reduces aquifer support. Tar characterization includes evaluation of the tar distribution and its sealing degree. It is an important prerequisite to optimize the water injection well’s requirement and placement to maximize sweep and recovery. This paper discusses a case study and demonstrates an integrated methodology by using static and dynamic data to determine the tar distribution and its sealing degree. The study includes both early life data before the subject field was put in production, as put on production, and post-production data to refine the characterization. Additionally, the use of formation pressure while drilling and Pyrolytic Oil-Productivity Index (POPI) analysis to optimize the injector’s placement will also be highlighted. Moreover, saturation and production logging tool analysis were incorporated to determine if there is aquifer influx across the tar mat. The degree of the aquifer influx is also evaluated using material balance and reservoir simulation. Introduction Field X is one of Saudi Aramco fields that was developed with four producing reservoirs namely, 1, 2, 3 and 4 reservoirs. The producing reservoirs have relatively good reservoir quality with average permeability of 310 md. The value is only one-third of average permeability from pressure build up which indicates an existence of fractures. The reservoir properties are relatively uniform.

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Petroleum exploration_developement_production_process

1. PETROLEUM EXPLORATION, DEVELOPMENT AND PRODUCTION PROCESS MUHAMMAD IMADUDDIN Managing Director, BAPEX BUET, 30 APRIL 2008

2. THE STAGES OF EXPLORATION AND DEVELOPMENT RECONNAISANCE DETAILING PROSPECT STRUCTURE DRILLING WELL RESULT DISCOVERY OR DRY REVIEW APPRAISAL DEVELOPMENT PRODUCTION

3. CONDITIONS OF FINDING PETROLEUM IS THERE A TRAP TO HOLD PETROLEUM Find a geological feature that can act as an accumulator of oil/gas IS THE TRAP SEALED Determine that the accumulator is sealed; oil/ gas cannot escape IS THERE A MIGRATION PATH A path must exist to allow flow of oil/gas to the trap IS THERE SOURCE MATERIAL OF PETROLEUM Area must had the material and environment to cook oil/gas

4. WHERE TO FIND A TRAP EXPLORATION IS EXPENSIVE, SO WHERE DO WE SEARCH WHAT ARE THE PRIORITIES WHY SOME AREAS ARE LESS EXPLORED FOCUS ON MORE PROSPECTIVE AREAS LOOK FOR LESS RISKY PROSPECT COMPREHENSIVE SURVEY NARROWS DOWN AREA FOR EXTENSIVE SURVEY

5. SURFACE GEOLOGY : THE INITIAL GUIDE GRAVITY MAP: THE FIRST INDICATION

6. STRUCTURAL VARIATION IN BANGLADESH

7. SEISMIC NETWORK THE FINAL IDENTIFICATION

8. SEISMIC DETAILING TO CONFIRM STRUCTURE

9. TYPE OF TRAPS TRAPS COULD BE STRUCTURAL: Anticline easy to locate with very low risk Fault bound easy to locate with fair risk STRATIGRAPHIC: Pinchouts tougher to locate with high risk Channels tougher to locate with high risk MORPHOLOGICAL Buried hill Reef

10. TYPES OF TRAPS

11. SEISMIC DATA SHOWING STRUCTURAL VARIATION

12. DRILLING TO CONFIRM Only when a structure is rated as prospective in terms of trap, seal, migration and source, it is drilled. A chance of success (COS/POS) of 20 to 35 % is considered risk worthy. Only 1 in 3 to 5 exploration wells find oil/ gas Drilling is expensive, risky and tough. Coring, logging, testing are part of drilling ops.

13. DRILLING AND DRILLING RIG

14. INCORPORATION OF DATA

15. HOW MUCH IS THERE After a well is drilled, it is logged i.e. parametric measurements are taken using electric, nuclear and sonic methods. Porosity, permeability, gas/ water saturation, pressure, salinity are calculated. Indicative zones are then perforated to test the flow of gas/oil. Testing certifies a well as discovery or dry. Discovery will lead to estimation of likely volume of oil/ gas in the structure. Initial estimation determines whether appraisal survey and wells are required.

16. APPRAISAL AND DEVELOPMENT DISCOVERY IS APPRAISED BY ADDITIONAL SEISMIC 2D/ 3D PRODUCTIVE ZONES ARE MAPPED FOR MORE ACCURATE EXTENT AND THICKNESS MORE WELLS ARE DRILLED TO CONFIRM THE APPARISAL RESERVE CALCULATED MORE ACCURATELY PRODUCTION LEVEL DETERMINED PRODUCTION WELLS ARE DRILLED FOR OPTIMISED PRODUCTION

17. HOW MANY WELLS IN A FIELD Once the reserve volume is determined number of wells that can be drilled is estimated. Volume of reserve, distribution of reservoir, type of depletion mechanism, economic considerations are guiding factors. Reservoirs may be continuous or discrete, depletion zone per well may vary, field life vis a vis investment required are major variables.

18. RESERVOIR VARIATION

19. RESERVOIR VARIATION

20. HOW MUCH PER WELL Production volume per day/ year from each field is based on the field producibility taking in to consideration field life cycle and economic investment. Each well is designed to produce an optimal volume based on the reservoir condition: porosity, permeability, petrology, saturation etc. Over production ignoring rock/ reservoir property will result in reservoir damage, loss of productive sand, water coning, sand infiltration etc.

21. HOW MUCH PER WELL Wells may have theoretical capability to produce more than its optimal flow; but it is undesirable to over produce wells to meet demand. Over production sustained for long period will cause loss of reservoir, leaving isolated zones that can not be produced; or deplete the field without recovering maximum reserve. Bakhrabad and Sangu are two significant example.

22. THANK YOU FOR YOUR KIND ATTENTION

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