A green field development project located in Sabah Basin comprises the whole upstream field development cycle from geology, reservoir studies to production facilities and economics. The objective is to come out with the best strategy to develop the field starting from our very own effort of reservoir characterization out of log and core data. Under supervision of lecturers, this project was completed as per scheduled.
Among new technical methodologies applied upon the completion this project:
1. Cubic Spline Interpolation Method in bulk volume calculation
2. Monte Carlo probabilistic method in reserve estimation
3. Reservoir Opportunity Index (ROI) method in well placement
Project was assessed by PETRONAS custodians.
This document discusses the design and operation of oil and gas pipelines and storage facilities. It covers key equations for calculating gas flow rates in pipelines, including the Weymouth, Panhandle A, and Modified Panhandle equations. Examples are provided to demonstrate how to use these equations to determine pipeline diameter and pressure drop given flow rates, temperatures, pressures, and other parameters. The document also addresses low pressure piping systems and provides equations for calculating pressure drop in plant piping.
Reserve Estimation of Initial Oil and Gas by using Volumetric Method in Mann ...ijtsrd
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
This document discusses different types of oil reservoirs based on their driving mechanisms and fluid compositions. There are six main driving mechanisms that provide natural energy for oil recovery: rock and liquid expansion, depletion, gas cap, water, gravity, and combination drives. Reservoirs are also classified based on their initial pressure and temperature relative to the fluid properties. Depending on initial reservoir pressure compared to the bubble point pressure, reservoirs can be undersaturated, saturated, or gas-cap. Gas reservoirs are classified based on their phase diagrams as retrograde gas-condensate, near-critical gas-condensate, wet gas, or dry gas. Development considerations vary depending on the reservoir type and conditions.
The document discusses various well completion methods and sand control techniques. It begins by explaining that well stimulation may be needed if the well's productivity has been impaired by the perforation or completion method. It then reviews different completion methods and their basic requirements to connect the reservoir, protect the casing, bring fluids to surface, provide safety measures, control sand, and provide zonal isolation. The document focuses on techniques for predicting and controlling sand production, including the use of screens, gravel packing, chemical consolidation, and frac and pack completions. It provides details on sieve analysis, gravel pack selection and sorting criteria.
The document discusses well deliverability and pressure drop in oil and gas wells. It explains that pressure drop is affected by properties of the reservoir fluids, production rates, and the mechanical configuration of the wellbore. Pressure loss is highest in the tubing and can be estimated using charts, correlations, or equations that consider fluid properties, flow rates, and well geometry. Matching inflow and outflow pressures gives the stabilized flow rate. The document compares methods for estimating pressure drop in single-phase and multiphase flow.
1. Gravel pack systems are used to control sand production in weak formations. Gravel is pumped into the annulus around a screen to block fine sand while allowing fluid flow.
2. The gravel pack assembly includes a packer, screen, blank pipe, centralizer, and bull plug. It is run in hole with the setting tool and packer. Pressure is applied to set the packer and release the setting tool.
3. Gravel slurry is then pumped through the work string, flowing out the window and filling the annulus around the screen. This blocks fine sand while maintaining production.
This document provides an overview and outline of a course on fundamentals of reservoir simulation. The course aims to review background on petroleum reservoir simulation and provide hands-on practice with Excel. The outline includes topics like flow equations for reservoirs, finite difference methods, single-phase and multiphase flow simulation. References are provided for additional reading.
I hope this presentation helps you to understand why we use acidizing process and calculations needed to perform the optimum acidizing .
Any questions contact me at karim.elfarash@std.suezuniv.edu.eg
WHY IS A RESERVES DEFINITION NEEDED?;
Classification Framework; Proven Reserves; Unproven reserves; Resources; RESERVES UNCERTAINTY CATEGORIES; PROJECT MATURITY SUB-CLASSES; PETROLEUM RESOURCES CLASSIFICATION BASED ON PROJECT STAGESOIL AND GAS PROJECT EVALUATION STAGES; OIL AND GAS PROJECT EVALUATION; PROJECT EVALUATION ; PROBABILITY OF SUCCESS (POSG)
1) The document discusses methods for determining reservoir pressure gradients, depths of fluid interfaces like gas-oil and oil-water contacts, and pressures at various points from measured well data.
2) Equations are provided to calculate pressure gradients between two depths, depths of hydrocarbon interfaces using gradients above and below the interface, and pressures at perforations or contacts using the gradient and depth.
3) An example problem demonstrates calculating gradients, gas-oil contact depth, oil-water contact depth, and pressures at the contacts and perforations using a table of depth and pressure measurements.
Analyzing Multi-zone completion using multilayer by IPR (PROSPER) Arez Luqman
The primary objective of any well drilled and completed is to produce Hydrocarbons; by loading the Hydrocarbon (i.e. Oil and Gas) contained within the well through a conduit of the well and start separating it with surface facilities depending on type and composition of the Hydrocarbon.
Producing oil is simultaneously contained with problems depending on the type and properties of the reservoir.
Furthermore, what makes the problems much more; is when oil and/or gas is produced from multi-zones at the same time, when accumulated problems from all the producer zones occurring at the same time.
To help analyze this problems we are going to use PROSPER software package IPR multilayer, in which helps in identifying the relationship between Flow rate and Reservoir pressure.
The acidizing is pumping of the acids into the wellbore to remove near well formation damage and other damaging substances, matrix acidizing is applied primarily to remove skin damage that caused by drilling, completion, work over, well killing or injection fluids.
This project is concerned with carbonate reservoirs that exceeded in Kurdistan subsurface formations.
Conduct a case study using real industrial data of Arab-D formation (Ghawar oil field – Saudi Arabia) which has five water wells were treated with 50 gallon of HCl acid The treatment acid was placed with coiled tubing and foam was used as diverter. The foam was made from nitrogen, water and surfactants.
Water injection pressure, injection rate and injection flow meter profiles prior to and after the treatment for the five wells show optimistic results to an acceptable extent
In coiled tubing acid placement, the coiled tubing/borehole annulus is usually filled with acid which allow the acid to be in contact with the entire zone at bottom hole temperature condition. This reduces the degree of diversion effectiveness.
Recommend people who work in carbonate reservoirs they should done their work on petrophysical analysis and the porosity should not have exceeded by the acids
This document discusses using the Ensemble Kalman Filter (EnKF) for history matching and production forecasts of oil reservoirs. It presents the EnKF algorithm and applies it to a synthetic 3D reservoir model. The EnKF allows updating reservoir properties like porosity and permeability from production data. Results show the EnKF ensemble matches observations better than without updating. Further work is needed to study the impact of observation availability and representativeness of the ensemble.
Integrated Oil Field Development Plan - FDP. Criteria, strategy and process f...Giuseppe Moricca
Integrated Oil Field Development Plan - FDP.
The integrated oil field development plan describes process, explores options, and targets, aimed at the optimal oil and gas field development in line with the oil company strategy.
The spine in the process is the specialist teams who navigate, manage and integrate the subsurface and surface complexities, uncertainties and opportunities into a single development plan, maximizing the overall field recovery and asset value.
Hydraulic fracturing involves pumping water mixed with proppant and additives into wells at high pressure to create fractures in rock formations and stimulate oil and gas production. The first successful hydraulic fracturing jobs occurred in the 1940s and 1950s. The process involves pad, slurry, and flowback stages. Parameters like in-situ stress, elastic properties, and fluid properties are considered for fracturing design. Fluid additives are used to carry proppant into the fracture and improve fluid properties. Pre-fracturing tests like step-rate and pump-in/flowback tests help determine fracture and closure pressures. Hydraulic fracturing has enabled production from tight shale and coalbed methane reservoirs.
This document describes various methods for generating and predicting inflow performance relationships (IPRs), including Vogel's method, Wiggins' method, and Standing's method. Vogel's method uses dimensionless parameters and curve fitting to develop IPR curves from reservoir simulation data. Wiggins' method similarly develops generalized IPR correlations through reservoir modeling. Standing's method extends Vogel's approach by introducing the zero-drawdown productivity index to allow prediction of future IPRs based on declining reservoir pressure.
CMG provides three reservoir simulation software packages: IMEX, GEM, and STARS. IMEX is a black oil simulator used for conventional reservoirs. GEM is a compositional simulator that can model complex fluid behavior, including processes where inter-phase mass transfer is important. STARS is an advanced simulator used for thermal modeling and complex reactions. It is the industry standard for modeling chemical EOR processes, including polymer flooding, low salinity flooding, and microbial EOR. CMG has extensive experience using STARS to model H2S bacterial souring through history matching and forecasting. Reservoir engineers can choose the appropriate CMG simulator based on the reservoir fluids and recovery process being modeled.
Skin factor is a dimensionless parameter that quantifies the formation damage around the wellbore. it also can be negative (which indicates improvement in flow) OR positive (which means formation damage exists). Positive skin can lead to severe well production issues and thus reducing the well revenue
This document summarizes key concepts from a reservoir engineering course, including pseudosteady-state (PSS) flow regimes for radial flow of slightly compressible (SC) and compressible (C) fluids. It discusses how the PSS flow condition is reached after transient flow, and how average reservoir pressure changes at a constant rate in PSS. Equations are provided for calculating flow rates of SC and C fluids in PSS, along with approximations that account for skin effect and non-ideal assumptions.
This document provides an overview of fundamental reservoir fluid properties and concepts. It discusses sampling and analyzing reservoir fluids, classifying hydrocarbons and their phase behaviors. Key fluid properties like gas, liquid, and formation water characteristics are examined. Common hydrocarbon types and compositions in crude oil and natural gas are also outlined. Fundamental reservoir engineering concepts involving hydrocarbon reserves calculations and fluid flow are reviewed.
Study project - Traffic engineering 2019Oleg Buyanov
Signal Setting Design and Synchronization in Via Tuscolana (Italy, Rome):
- Macro and Micro-simulation for transport arteria (Current situation and project) in PTV Visum and PTV Vissim
- Drawing Traffic Organization schemes
- Calculation of Traffic lights for each intersections
BDC VUB # 150 TTRC modified oct 26_KDKKevin Kelley
The document discusses performing a thru-tubing recompletion on well BDC #150. It recommends:
1) Perforating additional pay zones below the current zone using an e-line operation and installing a thru-tubing screen for sand control.
2) The recompletion is estimated to recover an additional 3 million barrels of oil with a net present value of $150 million.
3) The estimated cost of the recompletion is $120 million and it would payout within 4.4 months, providing an attractive return on investment.
This document summarizes a ship design project and presentation for a 2900 DWT oil tanker. The presentation covers determining preliminary principal particulars, preliminary lightweight, deadweight and displacement calculations, a preliminary general arrangement drawing, preliminary lines plan, and preliminary hydrostatic calculations. Key details presented include the vessel dimensions within restrictions for inland vessels in Bangladesh, preliminary principal particulars, general arrangement of spaces on board, offset tables, and hydrostatic curves showing metrics like displacement, waterplane area, trim, and stability at increasing drafts.
The document contains a weekly production review for PT. BAS covering the period of March 21-27, 2022. Key metrics reviewed include overburden removal which was 78% of plan for the week. Coal production was 44% of plan. Analysis identifies reasons for underperformance including rain, slippery conditions, and availability issues for loaders and haulers primarily related to waiting on trucks, fueling, and dust.
IRJET- Geotechnical Investigation of Different Soil Samples using Regression ...IRJET Journal
This document presents the results of a study that used regression analysis to develop equations to predict geotechnical properties of soils based on index properties. Soil samples were collected from various locations and tested in the laboratory to determine their California bearing ratio (CBR), maximum dry density (MDD), and optimum moisture content (OMC). Simple and multiple linear regression analyses were performed to establish relationships between these properties and index values like liquid limit, plastic limit, plasticity index, etc. Correlation coefficients were calculated. Equations were developed for CBR, MDD and OMC in terms of percentage compositions of industrial waste, fly ash, red mud, cement and lime stabilizers. Additional equations linked CBR to individual index properties.
This document provides an overview and marketing presentation for PT Medco Energi Mining Intl's coal mining and power operations in Nunukan, Indonesia. It summarizes the company's history and assets, which include nine oil and gas blocks and three coal mining concessions. It describes the geological challenges of mining multiple thin coal seams with varying quality. It highlights the company's operational excellence in utilizing in-house mining teams and infrastructure to maximize productivity and logistics. Finally, it discusses the company's marketing efforts to sell its high-sulfur coal to niche end users in cement and copper smelting.
This document provides the design of a security room structure. It includes calculations for loads on the structure from dead loads, live loads, and earthquake loads. It also includes modeling of the structure in STAAD Pro software, showing the joints, members, material properties, and load cases analyzed. Reinforced concrete design is performed for structural elements including the roof slab, foundation, and main structural members.
This document provides structural drawings and notes for a connecting bridge project at Masco Exports Ltd. It includes design codes and parameters used, concrete specifications and strengths, rebar specifications and development lengths. It also provides general notes on foundation type, concrete cover thickness requirements, lap splice lengths, and structural member details like slab end reinforcing and column splice locations. The consultant for this project is Geotech & Structures Limited.
Operation concerned Hydraulic set packer using tandem packer with mechanical set ETI-R3 for zonal isolation...in Mann Oil Field, Central basin of Myanmar.
This document contains drawings and specifications for building foundations and reinforcement. It includes 33 pages with various diagrams showing foundation plans, reinforcement details for slabs, columns, beams and other structural elements, and materials specifications. Page sizes range from A1 to A4 and include both landscape and portrait orientations.
Divine Somiari,S Well Bore Stability Presentationgillshood
The document discusses traditional well design methods versus using geomechanics for well planning. A case study from Nigeria shows that using geomechanics analysis, the well was able to be drilled to total depth with a lower mud weight than estimated by traditional methods, avoiding instability issues. The value of incorporating geomechanics into the well planning process is reducing drilling problems and costs through more accurate pressure and stability predictions.
The Gulf of Mexico OCS Region Update summarizes regulatory updates, Gulf of Mexico activity levels, and offshore safety priorities from the Bureau of Safety and Environmental Enforcement (BSEE) regional director. Key points include proposed new regulations on safety systems and blowout prevention, increasing permit approvals and rig activity in the Gulf, and a focus on operator compliance with Safety and Environmental Management Systems through audits and performance reviews. Loss of well control incidents have remained relatively steady in recent years despite increased activity levels.
The project involves designing a hard rock mine for a greenfield gold deposit located in Papua New Guinea. An initial pre-feasibility study has been conducted including cost estimation, pit optimization, and conclusion. Future tasks include developing an open pit and underground mine design using Vulcan software, reserve calculation, production scheduling, and further economic evaluation and risk assessment.
This document provides details of a highway construction project undertaken by Apco Infratech Pvt. Ltd. It summarizes the key project details including the client (IL & FS), location (Barwa-Adda-Panagarh section of NH-2 in Jharkhand and West Bengal), scope (6-laning of 43.325 km road), and contract value (Rs. 488 crores). It then provides progress updates on the status of road widening and structure construction works. Tables outline the monthly work planned and progress achieved between November 2015 to March 2016. Overall, it reports on the construction and management of a major highway project.
The document provides details of various CAE projects completed by Sarnath for different clients. It lists 13 clients from various industries that Sarnath has worked with on FEA, CFD and other simulation projects. It then describes Sarnath's domain expertise which includes customization, FEA, CFD, structural design, lean manufacturing, product development and reverse engineering. Finally, it provides brief descriptions and details of 20 different CAE projects completed for various clients across industries.
The document provides data from Maru-A Parts monthly inspection of fuel pipes supplied by ALBA Engineering Company. It summarizes inspection results for 30 samples across 17 inspection items for appearance, sizing, flaring, and air pressure tests. All samples passed inspection for the month of June, with no production issues reported. Dimensional measurements were within specification ranges.
This document contains a list of part numbers, revisions, pages and titles for various electrical drawings related to a DataPlace LCL system. It includes assemblies for printed circuit boards, electrical panels, sensors and other electrical and electronic components. Revisions provide information on changes made to drawings and released versions.
The document discusses plans to re-stimulate the A-35-10 #2 well in the Citronelle oil field. It provides background on the field and well, identifies the A-35-10 #2 as a candidate for re-fracturing based on its production history and location. Production forecasting estimates the well could see a 20% increase in production from a successful re-fracture. An economic analysis of 24 cases estimates positive returns depending on production rates and decline curves used. The proposed workover and re-fracturing plan aims to stimulate additional zones in the well.
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How to Manage Access Rights & User Types in Odoo 17Celine George
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3. Background & Problem Statement
Objectives & Scope of Study
Regional Geology, Petrophysics &
Volumetric
INTRODUCTION
2
4. Project
Background
Problem
Statement
Objective
The ultimate objective is to produce a
reasonable and reliable FDP report
that satisfies the needs of high-level
management in making decision of
the proposed development for
Gelama Merah field
Scope of Study
Reservoir Engineering
Drilling Engineering
Production Technology
Facility Engineering
Project Economic
Health, Safety & Environment
Facing time constraint, limited data
and large number of uncertainties,
the determination of the best
development options has been
considered as a tough challenge.
Summary Description
Block Name SB-18-12
Field Name Gelama Merah
Field
Location
Offshore Sabah,
Malaysia
Well name GM-1, GM ST-1
Well Type Exploration
Lithology Clay stone &
Sandstone
Field 29727503 m2
Marginal Field
Operator Contractor
3
6. REGIONAL GEOLOGY
• Sabah can be divided into 3 basins that are
characterized by distinct structural styles
and sedimentation histories
• Sabah Basin
• NE Sabah Basin
• SE Sabah Basin
Sabah Basin
• Located in East Baram Delta Province in Sabah Basin
• Gelama Merah field located in the West Labuan-Paisley
Syncline and identified by a major North-South growth
Morris Fault
• Deposited in the later part of Middle Miocene sands
Gelama Merah Field
4
7. PETROPHYSICS & VOLUMETRIC
Contacts
Log-Based
Method
Formation-Pressure
Method
GOC 1468.7 m TVD 1467.7 m TVD
WOC 1498.7 m TVD 1503 m TVD
Summary of Deterministic and Probabilistic Methods
Comparison of GOC and WOC
Oil Zone
Deterministic
Probabilistic
Petrel
P10 P50 P90
330 MMSTB 250 MMSTB 485 MMSTB 850 MMSTB 423 MMSTB
Gas Zone
Deterministic
Probabilistic
Petrel
P10 P50 P90
862 BSCF 678 BSCF 850 BSCF 955 BSCF 955 BSCF
5
9. RESERVOIR DATA REVIEW : SUMMARY
7
Information Value Source
Oil Rim Thickness 34.3 m Log & MDT
Initial Reservoir Pressure 2116 Psia PVT Report
Bubble Point Pressure 2028.7 Psia PVT Report
Oil Volume Factor 1.17 STB/bbl PVT Report
Average Permeability 140 mD DST Analysis
Average Porosity 0.27 Log
Average Water Saturation 0.36 Log
Rock Compressibility 3.22e-6 1/Psia Hall Correlation
Table: Gelama Merah Reservoir Data Summary
20. Offset Well Analysis
Well Trajectory
Mud & Cementing
Casing
Drilling Schedule
Drilling Problems & Technology
18
DRILLING ENGINEERING
21. OFFSET WELL ANALYSIS
19
1) GM-1 Well
2) GM ST-1 Well
3) Alab-1 Well
Alab-1 field is located 50 km
north-east of Labuan and 140 km
south-west of Kota Kinabalu.
Problems encountered
Pipe stuck
Shallow gas
22. WELL COORDINATES & RIG SELECTION
Types of MODUs Water Depth Average Daily Rate, USD
Jack-up rig 30 – 500 ft 77,813 - 143,496
Tender Assisted rig Anchor length 44,463 - 117,780
Semi-submersible
rig
150 – 6000 ft 300,279 – 396,342
Drill ship/ Large
Submersible
1000- 8000 ft 237,900 – 420,324
Figure: Well Coordinates
Table: Rig
Selection
• Jack up rig is chosen.
• Platform 1 as mother platform, Platform 2
as an unmanned platform
• Water depth : 42.8 m = 140.2ft
• 6 deviated wells and 1 vertical well (7
wells)
• Well 4 and Well 7 functions as appraisal
wells
20
24. MUD WINDOW & CASING DEPTH
Type of Casing Depth (Ft-SS) Hole Size Casing Size
Conductor casing 0 - 360 Piled case 20"
Surface casing 360 - 2170 17.5" 13.375"
Production casing 2170 – Target Depth 12.25" 9.625"
Figure: Mud Window
22
Seabed – 229.92 ft
RT
25. CASING SELECTION, WELL SCHEMATICS &
CEMENTING
Type of casing OD (inch) Grade
Nominal
Weight (lb/ft)
Collapse
Pressure (psi)
Internal Yield
Pressure (psi)
Joint Strength
1000 lbs
ID
(inch)
Connection
Type
Conductor 20 API 5L X-56 154.0 2140 3680 2540 18.500 XLC-S
Surface 13 3/8 J-55 54.5 1130 2730 909 12.615 BTC
Production 9 5/8
VAM TOP
( 80 ksi )
40.0 3080 5750 916 8.75 VAM TOP
Casing Type
Total
Cement
Slurry
(cu.ft)
No of sacks
(sk)
Mix Water
Required
(gal)
Additive
(cu.ft)
Surface 25348.739 21301.462 110767.60 5069.74
Production 28541.731 24187.908 125777.12 5708.34
Total 53890.471 45489.370 236544.72 10778.09
Conductercasing
20''piled-360 ft
seabed
Seabed-229.92 ft RT
Surface casing 13
3/8' 360 ft-2170 ft
Productionsasing
9 5/8 - 2170ft -TD
17 1/2''Hole
17 1/2''Hole
TOCSurface &
Productioncasing
at seabed
Table : Casing selection and grade
Table : Well Cementing
Figure : Well Schematics
23
26. BIT SELECTION AND DRILLING FLUID
Interval Surface Production
Hole size (in) 17 1/2 12 ¼
Casing OD (in) 13 3/8 9 5/8
Bit diameter (in) 17 1/2 12 ¼
Depth in (m-RT) 70.1 732
Depth out (m-RT) 732 Target Depth
Roller cone bit & PDC bit
Depth,TVD-
SS (ft)
Mud Weight
(ppg)
Mud design
70.1 – 2170.0 8.7 Seawater Polymer Mud
2170.0 –
Target Depth
9.8 WBM - KCL/PHPA
Table: Bit Selection
Table: Drilling Fluid
• WBM is chosen,
• OBM and SBM are expensive and
mainly for HPHT wells
• Shale inhibitor is required :
Partially-hydrolyzed Polyacrylamide
(PHPA) + KCL
• Polycrystalline Diamond Compact bit
(PDC) can operate in medium hardness
formation and also hydratable
sediments; sand and shale.
• Economically wise, PDC can’t be used
throughout the drilling
• Roller cone bits will be used with PDC
as the alternative option when rock bit
faces high wear rate
24
27. DRILLING SCHEDULE
Year 2017
TaskName Startdate TimeTaken Jan Feb Mac April May June July Aug Sept Oct Nov Dec Jan
GelamaMerah
Platform1 24-Feb-16 5
Well4 1-Mar-16 40
Well1 11-Apr-16 40
Well2 21-May-16 40
Well3 1-Jul-16 10
Platform2 11-Jul-16 10
Well7 21-Jul-16 40
Well5 1-Sep-16 40
Well6 11-Oct-16 40
Demob 21-Nov-16 5
270
2016
Figure: Drilling Schedule
25
28. DRILLING PROBLEMS & TECHNOLOGY
Figure: Drilling Schedule
26
Drilling problems are identified from the offset well analysis. Here are the possible problem that may occur:
I. Pipe stucking
II. Shallow gas
III. Lost circulation
IV. Kick & Blowout
Drilling technology assists the team in overcoming possible drilling problems. Here are some technologies
which can be used for the drilling plan.
I. Drill Dog™ Electro-Magnetic Measurement While Drilling
II. Cement Assurance Tool (CAT)
III. Directional Casing While Drilling (DCwD)
31. Figure : IPR at Reservoir Pressure 2116 psia
PI : 3.95STB/day/psi
AOF : 4724.8STB/Day
PRODUCTION TECHNOLOGY PLAN
IPR Curve
Well Performance Analysis
Reservoir pressure 2116 psia
Reservoir temperature 155 *F
Water cut 0 %
Fluid Oil and water
Method BLACK OIL
GOR 336 scf/stb
Oil gravity 27.3 API
Gas gravity 0.745 sg
Water salinity 30000 ppm
H2S 0 mole%
CO2 0.62 mole%
N2 0.57 mole %
29
36. Functional Requirement Component
Optimize production Tubing Size ID 2.75”
Isolate producing zones Packer
Emergency containment subsurface controlled sub
safety valve (SCSSV)
Gas lift valve installation Side pocket mandrel (SPM)
Routine down-hole operation Xmas tree
Isolation devices that prevent
communication between the
tubing and the annulus.
Dummy valve
WELL COMPLETION MATRIX
Table : Completion String Components
Well Name Type
Perforated
interval, m
Remark
P1 Deviated 1502 - 1540 Producer
P3 Deviated 1505 - 1534 Producer
P5 Deviated 1499 - 1522 Producer
P6 Deviated 1468 - 1496 Producer
P8 Deviated 1503 - 1519 Producer
P9 Deviated 1496 - 1525 Producer
GLM Vertical 1521 - 1530 Producer
Table : Production Well & Perforation Interval
34
37. WELL COMPLETION MATRIX
Figure: Completion Schematic
Wellhead equipment that meets API Specification 6A
(equivalent to ISO 10423) is available in standard pressure
increments:
• 13.8 MPa (2000 psi)
• 20.7 MPa (3000 psi)
• 34.5 MPa (5000 psi)
• 69.0 MPa (10,000 psi)
• 103.5 MPa (15,000 psi)
• 138.0 MPa (20,000 psi)
• 207 MPa (30,000 psi)
35
38. Rod pump PCP
ESP Gas Lift
Artificial
Lift
• Low operating cost. Compression cost depends on the fuel
cost and compressor maintenance.
• Suitable for both conditions (gas coned well and water
coned well)
• Gas lift is believed to have a longer lifespan (10-20 years)
Gas Lift Method Justifications
ARTIFICIAL LIFT RECOMMENDATION
36
39. • Preference : Continuous Gas lift
• Reasons :
High gas-oil ratio (GOR) produced fluid.
High reservoir inflow productivity index.
Use of side pocket mandrels allows easy wireline
replacements of gas lift valves.
Sufficient producing gas to be used as injecting
gas.
ARTIFICIAL LIFT RECOMMENDATION
37
40. ARTIFICIAL LIFT DESIGN
Maximum gas available, which is the
amount of gas present in the reservoir
Maximum gas during uploading which
the gas each well can handle.
Water cut which was set at 50 %
Figure: Gas lift design data selection.
38
41. Figure: Gas lift vales MD proposed by PROSPER
Type
GLV #1 GLV #2 GLV #1
IPO IPO Orifice
Size 1.5 1.5 -
Setting Depth, MD
P1 760 1233 1489
P3 765 1228 1495
P5 768 1231 1496
P6 750 1235 1490
P8 755 1222 1487
P9 760 1233 1499
Pilot Well, GLM 767.157 1230.43 1494
Gas lift must be installed above production packer
ARTIFICIAL LIFT DESIGN
39
44. Exporting
Processing
Extraction
Facility
*** Main design requirement:
Water depth
Environmental
conditions
Number of wells
Equipment
requirements
Life of the field
Frequency of
human
intervention on
the platform
Interfacing
requirements
42.8 m
not very harsh but with
alternating monsoon
period.
7 deviated wells
Integrated WHP-CPP-LQ in
single Jacket
20 years.
24/7
subsea pipeline system
42
45. Location of wells and platforms Topside Structure Schematics
Subsea Structure SchematicsEquipment Arrangement plan
WHY Jacket?
Support large deck loads
Large field, long term
production
Piles result in good stability
Little effect from sea floor
scour
Used for production up to
130m water depths
Cheaper
43
46. Dry Tree Wet Tree
Advantages
Tree and well control at surface
in close proximity of people
Direct vertical access to wells for
future intervention activities
Minimal offshore construction
Enable future drilling and
expansion
- Tree and well access the
seabed isolated from people
- Full range of gull types can be
used
- Simplified riser/vessel
interfaces
- Preferable for deep water
installation
Christmas Tree
Wellhead and Manifold
Conventional Approach Multiport Flow Selector (MPFS)
Complex piping arrangement / valves /
actuators and controls
Simple piping arrangement with
minimum valves
Large number of leak points risking
production downtime
Reduced leak points
Occupies more space and much higher
weight
Compact system, reduced space and
weight
Prone to Human error Reduced/ minimum human error
Expensive Economical
Manifold
44
47. Separator
Reciprocating Compressor Centrifugal Compressor
- Low horsepower (< 2,000 hp)
- High-ratio applications
- Size up to 10,000 hp
- Higher fuel efficiency
- Much higher turndown
capabilities
High horsepower (>4,000 hp)
For low ratio (<2.5) in 1000 hp
Cheaper
Takes less space
Less weightage
Has higher availability
Lower maintenance costs
Compressor
Gas Lifting Surface Facility
Horizontal Vertical Spherical
Can handle much higher GOR
Cheaper than the vertical
separator
Easier and cheaper to ship and
assemble
greater liquid capacity
Reduces turbulence and reduces
foaming, thus it can handle
foaming crude
- Easier to clean
- Save space
- Provides better
surge control
- Liquid level control
is not critical
- Cheapest
- Better
clean-out
45
48. Produced Water Treatment
Gas and Oil Metering system
Flaring and Venting System
Multiphase
flow meter
(MPFM)
Simple Design
Low maintenance cost
Reliability
Weight and space reduction ability
Emergency Shutdown System
* ESD valves for flowline and pipeline should be located away
from facility.
46
* The Flaring system
contains of a flare boom
linked with pipes to
accumulate the gas to be
burnt.
Drainage System
Open Drains –water from rain, seawater spray.
Closed Drains – collects water from process areas, where water is polluted
and hazardous
49. Power Generator Type Advantages
Gas Turbines
Economic for continuous operation of
generators
Tolerant to high ambient conditions and
elevations
Low owning and operating costs
Best fuel efficiency
Low emission level
No local fuel storage requirement
Diesel Generator
Renewable Energy
High voltage direct current
Power Generation Communication Links
Seawater Systems
Helifuel System
Link type Advantage
Microwave line
of sight
Low cost equipment, high
capacity, high reliability.
Troposcatter
High capacity, high
reliability, no delay, no
recurring monthly
costs, distance 30-250
km.
Fresh water system - Vapour Vacuum Compression (VVC) distillation
Cooling system for generators, ventilation, and air conditioning
Washing facilities - the treatment for water from kitchen, showers and
toilets before being discharged to sea.
Bilge system is a pump system that is used to prevent from flooding of
machinery spaces and pump rooms.
Fixed fire fighting system: fire main and helideck foam systems
* Fuel filter
* Flow meter
* Hose reels with dispensing nozzles
* Electric bonding and spill containment foam based fire fighting system
Sand Separation System
* The sand that separated from hydrocarbon fluids should
be removed and transported ashore for disposal.
47
50. Pipeline System: safe, high efficiency for oil transmission, wide transmission capacity, high
economic profit for long life field.
Petronas’s Samarang (1975) oil field with 6-
in. OD natural gas pipeline and 8-in. OD
crude oil pipeline.
Pipeline Flow Assurance:
Hydrate formation
Maintain system operating pressure lower
than hydrate formation threshold
Corrosion Protection System:
Internal Protection
External Protection Cathodic protection
DC current through metal
Corrosion inhibitors
Pigging debris
Location of GM and Samarang fields
48
51. 49
Revenue Over Cost PSC
Fiscal Terms
Economic Assumptions
Development Options
Economic Analysis
PROJECT ECONOMICS
52. REVENUE OVER COST PSC (1997)
• Encourage additional investment in
Malaysia’s small/marginal oil and
gas discoveries
• Allows contractors to accelerate
their cost recovery if they perform
within certain cost targets
• Allow contractor to own higher
share of profit when their
profitability is low
• Increase NOC’s share of profit when
the contractor’s profitability
improves
• Essentially a self-adjusting formula
of =
Cumulative Revenue
Cumulative Cost
50
Gross
Revenue
Profit Split
Contractor : NOC
(Depends on R/C)
Cost Ceiling
(Depends on R/C)
Government Cash
Flow
Petroleum Income Tax 38%
Royalty 10%
Petroleum Income Tax 38%
Cost
Ceiling
Contractor’s Profit
Contractor Cash
Flow
NOC Cash Flow
NOC Profit
53. FISCAL TERMS
Contractor’s
R/C Index
Cost
Ceiling
(%)
Profit Ratio (%)
Below THV
NOC : Contractor
Above THV
NOC : Contractor
0.0 < R/C <= 1.0 70 20 : 80 60 : 40
1.0 < R/C <= 1.4 60 30 : 70 70 : 30
1.4 < R/C <= 2.0 50 40 : 60 70 : 30
2.0 < R/C <= 2.5 30 50 : 50 70 : 30
2.5 < R/C <= 3.0 30 60 : 40 70 : 30
R/C > 3.0 30 70 : 30 90 : 10
Note: Oil THV (30 MMSTB) and Gas THV (750 BSCF)
Terms Details
Royalty 10%
Export Duty 10%
Petroleum Income Tax 38%
Contract Period:
Exploration
Development
Production
3 years
4 years
20 years
Research Cess 0.5% (Not inclusive in Cost Oil)
Cost Ceiling Sliding Scale (Up to 70%)
Profit Sharing R/C Index (Max 70%)
NOC Participation Min 15%
Supplementary Payment 70%
51
Table: Fiscal Terms
Table: R/C Index
54. ECONOMIC ASSUMPTIONS
Fiscal Terms Export Duty, Research Cess and NOC Participation was not taken into account.
Reference Year The year of evaluation is 2016.
First Oil The first oil to be produced from Gelama Merah is expected to be in 2020.
Production Period
A production period of 20 years is expected with a plateau of approximately 10642
stb/day for the first 10 years and then declining.
Decommissioning Year Decommissioning period will be after 20 years of production period in 2039.
Oil and Gas Price
The oil and gas price is assumed to be $60/bbl and $4/mscf respectively based on
previous oil crash trends.
OPEX
The base OPEX is obtained to be approximately $6.35 million/year but will increase
based on the requirement for gas lift and produced water treatment.
Compounding Factor An escalation of 2.5% per annum is assumed to account for the inflation rate.
Discount Rate
Assumed to be 10% WACC during the evaluation according to the opportunity cost
of capital, acquisition cost of capital and risk management.
52
55. DEVELOPMENT OPTIONS
Criteria Unit Option 1 Option 2 Option 3
Cumulative Oil MMSTB 49.08 54.03 56.45
Cumulative Gas TSCF 1.13 1.09 1.11
Cumulative Water MMSTB 20.21 5.28 4.52
CAPEX $MM 247.75 290.75 301.75
NPV @ 10% $MM 564.71 406.11 392.94
IRR % 47 28 28
Payout Period Years 2.19 3.74 3.79
PIR Ratio 6.02 5.31 4.79
Drilling Option
Option 1: 7 Deviated wells
Option 2: 5 Deviated and 2 horizontal wells
Option 3: 4 Deviated and 3 horizontal wells
Facility Option
Option 1: Tie-in pipeline to Samarang pipeline
Option 2: Pipeline to LCOT
Criteria Unit Option 1 Option 2
CAPEX $MM 247.75 289.51
NPV @ 10% $MM 564.71 552.19
IRR % 47 41
Payout Period Years 2.19 2.48
PIR Ratio 6.02 5.05
53
60. Objectives:
To minimize any negative impact that may occur
To reach the highest possible level of safety
To protect its employees, contractors,
customers and local surrounding
HEALTH, SAFETY AND ENVIRONMENT
58
Safety precaution when
conducting exploration,
development and abandonment
61. Example of HSE plan
• PETRONAS Health,
Safety & Environment
Management System
(HSEMS)
• Comply to PETRONAS
Regulatory
• Any negligence or
deviation should be
justified.
HSE DEVELOPMENT PLAN
59
62. Before Exploration
• Secure the area
• Risk assessment
• Selection of contractor and
equipment
During Exploration
• Periodic inspection
• HSE Training Programme
• Cultivate awareness
• Practice emergency drill
Development
• Risk assessment
• Determine treatment
system
Production
• System selection to control
flow rate
• Pipeline inspection for
corrosion purpose
Abandonment
• Determine depth to plug the
well
• Inspection of any
contamination
• Recycle/dispose equipment
HSE DEVELOPMENT PLAN
60
63. 1
• HSE Policy and Strategy Objective
2
• Organization
3
• Arrangement
4
• Risk Management
5
• Planning and Procedure
6
• Implementation and Performance Monitoring
HSE MANAGEMENT SYSTEM
Figure : HSE Management System
61
64. ABANDONMENT
• Comply with minimum requirement for Plug and
Abandonment(P&A)
• Plug must be verified by the particular engineer that in charge
for particular well
• Well P&A programme and suspension should be submitted to
PETRONAS for approval
62
Perforate