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Coil Tubing Unit for Oil Production and Remedial Measures [Hardback]

(University of Technology and Applied Sciences, Nizwa, Oman)
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Coil Tubing Unit for Oil Production and Remedial MeasuresPalielināt
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Permanent link: https://www.kriso.lv/db/9788770226905.html
Keywords:
Well activation is one of the most important aspects in the oil and gas industries and nitrogen gas is predominately used. The gas, being light, is sent down the producing reservoir which will enhance the production or improve the flow of crude oil. In addition to the methods used to increase production there are several problems like sand production and water production from the producing wells.

Sand production occurs when the destabilizing stresses at the formation face exceed the strength of the natural arching tendencies and/or grain-to-grain cementation strength. Ideally, during oil production, the formation should be porous, permeable and well consolidated through which hydrocarbons can easily flow into the production wells. But sometimes, especially during production from unconsolidated sandstone reservoirs, the produced hydrocarbons may also carry large amounts of sand into the well bore and sand entering production wells is one of the oldest problems faced by oil companies and one of the toughest to solve. These unconsolidated formations may not restrain grain movement, and produce sand along with the fluids especially at high rates.

Water production is also a problem that many reservoir or production engineers face in day-to-day life. As engineers we should be able to decide whether water control solutions should be applied or not. The excess production of water is caused by the depletion of the reservoir and simply sweeps away most of the oil that the reservoir can produce.

This book gives an information how well activation using nitrogen is carried out, and how sand control and water control issues can be resolved.

This book gives an information how well activation using nitrogen is carried out, and how sand control and water control issues can be resolved.



Well activation is one of the most important aspects in the oil and gas industries and nitrogen gas is predominately used. The gas, being light, is sent down the producing reservoir which will enhance the production or improve the flow of crude oil. In addition to the methods used to increase production there are several problems like sand production and water production from the producing wells.

Sand production occurs when the destabilizing stresses at the formation face exceed the strength of the natural arching tendencies and/or grain-to-grain cementation strength. Ideally, during oil production, the formation should be porous, permeable and well consolidated through which hydrocarbons can easily flow into the production wells. But sometimes, especially during production from unconsolidated sandstone reservoirs, the produced hydrocarbons may also carry large amounts of sand into the well bore and sand entering production wells is one of the oldest problems faced by oil companies and one of the toughest to solve. These unconsolidated formations may not restrain grain movement, and produce sand along with the fluids especially at high rates.

Water production is also a problem that many reservoir or production engineers face in day-to-day life. As engineers we should be able to decide whether water control solutions should be applied or not. The excess production of water is caused by the depletion of the reservoir and simply sweeps away most of the oil that the reservoir can produce.

This book gives an information how well activation using nitrogen is carried out, and how sand control and water control issues can be resolved.

Preface xiii
List of Figures
xv
List of Tables
xvii
List of Abbreviations
xix
1 Nitrogen Application
1(30)
1.1 Introduction
1(1)
1.2 History of N2
2(1)
1.2.1 N2 Properties
3(1)
1.3 Cryogenics
3(2)
1.3.1 Introduction
3(2)
1.4 Basic Equipment
5(3)
1.4.1 Storage Tank
7(1)
1.4.2 Pumping System
7(1)
1.4.3 Vaporizer System
7(1)
1.5 Safety
8(3)
1.5.1 General Information
8(1)
1.5.2 Safety Bulletin from CGA (Compressed Gas Association)
9(1)
1.5.3 Oxygen-deficient Atmospheres
10(1)
1.5.4 Safety for Handling and Exposure
11(1)
1.6 N2 Service Applications
11(11)
1.6.1 Displacement
12(3)
1.6.2 Nitrified Fluids-Acidisation
15(1)
1.6.3 Atomized Atom
16(1)
1.6.4 Foamed Acid
17(1)
1.6.4.1 N2 Retention
17(1)
1.6.4.2 Diverting
18(1)
1.6.4.3 Production of Fines
18(1)
1.6.4.4 Foamed Acid Guidelines
19(1)
1.6.5 Aerating Conventional Fluids
19(1)
1.6.6 Pipeline Purging
20(1)
1.6.7 Use of Foam as a Drilling and Workover Fluid
20(2)
1.7 Foam Clean Out
22(2)
1.7.1 Introduction
22(1)
1.7.2 Foam Stability and Viscosity
23(1)
1.7.3 Fire Control
24(1)
1.8 Water Control Technique by N2 Injection
24(4)
1.8.1 Introduction
24(1)
1.8.2 Technology
25(1)
1.8.3 Job Description
26(1)
1.8.4 Commercial Viability
26(1)
1.8.5 Quick and Easy
26(1)
1.8.6 Versatility and Adaptability
26(1)
1.8.7 Economical
26(1)
1.8.8 Freeding Differentially Stuck Drill Pipe
27(1)
1.8.8.1 N2 Lift
28(1)
1.8.8.2 N2 cushion
28(1)
1.9 Case Study - I
28(1)
1.10 Results/Remarks
29(1)
1.11 Conclusion
30(1)
1.12 Specification of N2 Pumpers Available with WSS COLD END
30(1)
2 Water Control
31(38)
2.1 Introduction to Water Production
31(6)
2.1.1 Methods to Predict, Prevent, Delay and Reduce Excessive Water Production
32(1)
2.1.1.1 Oil and Water production rates and ratios
32(1)
2.1.1.1.1 Material Mass Balance
32(1)
2.1.1.1.2 Darcy's Law
33(1)
2.1.1.1.3 Productivity index
34(1)
2.1.1.1.4 Simulators
34(1)
2.1.1.2 Rate-limited facilities
34(1)
2.1.1.3 Water production effect on bypassed oil
35(1)
2.1.1.4 Reservoir maturity
35(1)
2.1.1.5 Water production rate effect on corrosion rates
36(1)
2.1.1.6 Water production rate effect on scale deposition rates
36(1)
2.1.1.7 Water production rate effect on sand production
36(1)
2.2 Water Production Mechanisms
37(4)
2.2.1 Completions-Related Mechanisms
37(1)
2.2.1.1 Casing leaks
37(1)
2.2.1.2 Channel behind casing
38(1)
2.2.1.3 Completion into Water
38(1)
2.2.2 Reservoir-Related Mechanisms
38(1)
2.2.2.1 Bottomwater
38(1)
2.2.2.2 Barrier breakdown
38(1)
2.2.2.3 Coning and cresting
39(1)
2.2.2.4 Channeling through high permeability
39(1)
2.2.2.5 Fracture communication between injector and producer
40(1)
2.2.2.6 Stimulation out of zone
41(1)
2.3 Preventing Excessive Water Production
41(8)
2.3.1 Preventing Casing Leaks
41(1)
2.3.2 Preventing Channels Behind Casing
41(1)
2.3.3 Preventing Coning and Cresting
42(1)
2.3.4 Perforating
42(1)
2.3.5 Fracturing
43(1)
2.3.6 Artificial Barriers
43(1)
2.3.7 Dual Completions
43(1)
2.3.8 Horizontal Wells to Prevent Coning
43(1)
2.3.9 Preventing Channeling Through High Permeability
44(1)
2.3.9.1 Perforating
45(1)
2.3.9.2 Stimulation techniques
45(1)
2.3.9.3 Permeability reduction
46(1)
2.3.9.4 Preventing fracture communication between injector and producer
47(1)
2.3.9.5 Completing to accommodate future water production rates future zonal isolation
48(1)
2.4 Creative Water Management
49(2)
2.5 Treatments Used to Reduce Excessive Water Production
51(11)
2.5.1 Characterizing the Problem
51(1)
2.5.2 Treatment Design
52(1)
2.5.3 Expected Treatment Effect on Water Production
52(1)
2.5.4 Treatment Types
53(1)
2.5.4.1 Zone sealants
53(1)
2.5.4.2 Permeability-Reducing Agents (PRA)
54(1)
2.5.4.3 Relative Permeability Modifiers (RPM)
55(1)
2.5.5 Description of Previously Applied Treatments
56(1)
2.5.5.1 Mechanical plugs
56(2)
2.5.5.2 Sand plugs
58(1)
2.5.5.3 Water-based cement
58(1)
2.5.5.4 Hydrocarbon-based cements
58(1)
2.5.5.5 Externally activated silicates
58(1)
2.5.5.6 Internally Activated Silicates (IAS)
58(1)
2.5.5.7 Monomer systems
59(1)
2.5.5.8 Crosslinked polymer systems
59(1)
2.5.5.9 Surface-active RPMs
60(1)
2.5.5.10 Foams
60(1)
2.5.6 Treatment Lifetime
60(2)
2.6 Selecting Treatment Composition and Volume
62(3)
2.6.1 Placement Techniques
63(1)
2.6.1.1 Bullheading
63(1)
2.6.1.2 Mechanical packer placement
63(1)
2.6.1.3 Dual injection
63(1)
2.6.1.4 Isoflow
63(1)
2.6.2 Viscosity Considerations
64(1)
2.6.3 Temperature Considerations
64(1)
References
65(4)
3 Sand Control
69(60)
3.1 Sand Control Introduction
69(3)
3.1.1 Formation Damage
69(1)
3.1.2 Fines Migration
70(1)
3.1.3 Sand Production Mechanisms
71(1)
3.2 Formation Sand
72(3)
3.2.1 Petro Physical Properties
73(1)
3.2.2 Geological Deposition of Sand
73(1)
3.2.2.1 Desert aeolian sands
73(1)
3.2.2.2 Marine shelf sand
73(1)
3.2.2.3 Beaches, barriers and bar
74(1)
3.2.2.4 Tidal flat and estuarine sands
74(1)
3.2.2.5 Fluviatile sands
74(1)
3.2.2.6 Alluvial sands
74(1)
3.2.3 Formation Sand Description
74(1)
3.2.3.1 Quicksand
74(1)
3.2.3.2 Partially consolidated sand
75(1)
3.2.3.3 Friable sand
75(1)
3.3 Causes and Effects of Sand Production
75(2)
3.3.1 Causes of Sand Production
75(1)
3.3.1.1 Totally unconsolidated formation
75(1)
3.3.1.2 High production rates
75(1)
3.3.1.3 Water productions
76(1)
3.3.1.4 Increase in water production
76(1)
3.3.1.5 Reservoir depletion
76(1)
3.3.2 Effects of Sand Production
76(1)
3.4 Detection and Prediction of Sand Production
77(1)
3.4.1 Methods for Monitoring and Detection of Sand Production
77(1)
3.4.1.1 Wellhead shakeouts
77(1)
3.4.1.2 Safety plugs and erosion sand probes
77(1)
3.4.1.3 Sonic sand detection
77(1)
3.5 Methods for Sand Exclusion
78(2)
3.5.1 Production Restriction
78(1)
3.5.2 Mechanical Methods
79(1)
3.5.3 In-Situ Chemical Consolidation Methods
79(1)
3.5.4 Combination Methods
79(1)
3.5.5 Selecting the Appropriate Sand Exclusion Method
80(1)
3.6 Mechanical Methods of Sand Exclusions
80(12)
3.6.1 Mechanical Components
83(1)
3.6.1.1 Pack-sands
83(1)
3.6.1.2 Liners and screens
83(3)
3.6.1.3 Carrier fluids
86(3)
3.6.2 Tools and Accessories
89(1)
3.6.3 Completion Tools
89(1)
3.6.3.1 Gravel-pack Packer
89(1)
3.6.3.2 Flow sub
89(1)
3.6.3.3 Mechanical fluid-loss device
89(1)
3.6.3.4 Safety joint
90(1)
3.6.3.5 Blank pipe
90(1)
3.6.3.6 Tell-tale screen
90(1)
3.6.3.7 Seal assembly
90(1)
3.6.3.8 Sump packer
91(1)
3.6.4 Service Tools
91(1)
3.6.4.1 Crossover service tool
91(1)
3.6.4.2 Reverse-ball check-valve
91(1)
3.6.4.3 Swivel joint
91(1)
3.6.4.4 Washpipe
91(1)
3.6.4.5 Shifting tools
92(1)
3.6.4.6 Tool selection
92(1)
3.7 Mechanical Method: Techniques and Procedures
92(19)
3.7.1 Gravity Pack
93(1)
3.7.2 Washdown Method
93(1)
3.7.3 Circulation Packs
93(1)
3.7.4 Reverse-circulation Pack
94(1)
3.7.5 Bullhead Pressure Packs
94(1)
3.7.6 Circulating-pressure Packs
94(1)
3.7.7 Slurry Packs
95(1)
3.7.8 Staged Prepacks and Acid Prepacks
96(1)
3.7.9 Water-packs and High-rate Water-packs
96(1)
3.7.10 Fracpacks
97(1)
3.7.11 Summary
97(1)
3.7.12 Mechanical Job Designs
98(1)
3.7.12.1 Formation characteristics
98(2)
3.7.12.2 Pack-sand selection criteria
100(2)
3.7.12.3 Screen selection criteria
102(4)
3.7.12.4 Gravel-pack job calculations
106(1)
3.7.12.4.1 Pack-sand volume required
106(3)
3.7.12.4.2 Carrier-fluid Volume
109(1)
3.7.12.5 Predicting job outcome by computer modeling
110(1)
3.8 Chemical Consolidation Techniques
111(5)
3.8.1 Internally Activated Systems
114(1)
3.8.2 Externally Activated Systems
114(1)
3.8.3 Application
115(1)
3.9 Combination Methods
116(3)
3.9.1 Semicured Resin-coated Pack Gravels
116(1)
3.9.2 Liquid Resin-coated Pack Gravel
117(2)
3.10 Horizontal Gravel-Packing
119(7)
3.10.1 Variables that Affect Sand Delivery
121(1)
3.10.2 Pump Rate and Fluid Velocity
121(1)
3.10.3 Alpha and Beta Wave Progression Through the Annulus
122(1)
3.10.4 Sand Concentration
123(1)
3.10.5 Placement Procedure and Tool Configuration
124(1)
3.10.6 Liner/Tailpipe Ratio
125(1)
3.10.7 Screen/Casing Clearance
125(1)
3.10.8 Perforation Phasing
126(1)
References
126(3)
Index 129(4)
About the Author 133
Mohammed Ismail Iqbal is currently working as a faculty member at University of Technology and Applied Sciences in Oman and has approximately 11 years of experience nationally and internationally in both teaching and academia. He is pursuing a PhD from Lincoln University College in Malaysia, and has finished a Masters in Oil and Gas Engineering from University of Salford, United Kingdom, an MBA in Oil and Gas Management from Petroleum University, and a Bachelors in Mechanical Engineering from Osmania University.



 



Mr Iqbal has strong corporate relations and industry links, and has designed courses for UVM (Mexico), providing training to big IT giants like ITC Infotech, L&T IES, CAIRN, HCL, PETROSERV, BAPEX, setting up a drilling rig on the UPES campus, which is the first university in India. He has expertise in quality, accreditation, institutional planning (strategic planning, operational planning), quality assessment and experience in launching new programs in digital transformation age of Industry 4.0.



 



His research interests are production optimization techniques using software like PIPESIM, enhancing recovery well productivity using well testing software like PANSYS, kappa and reservoir simulation using software named RFD, drilling optimization, and development of new chemical for sand control treatment, to name a few.



 



He has published research papers in Elsevier, Scopus Journal, and peer reviewed journals in the research area mentioned above nationally and internationally, and also holds copyright for a research idea (risk assessment) and very recently filed a patent on classroom monitoring during social distancing.