The document discusses various issues encountered with rod pump systems in Agiba oil fields and the remedial actions taken. It covers problems like gas interference, fluid pounding, scale deposition, sucker rod failures, sand production, stuck pumps, and tubing wear. Tests of techniques like gas anchors, variable slippage pumps, hollow sucker rods, and roller guides are summarized. Common troubleshooting indicators and techniques are also outlined, along with practices to avoid.
The slide-pack covers a large variety of artificial lift methods. Explanations are supported by breakdown of pros and cons, calculations and questions. Questions will shed light of roughly how to decide which method(s) to use in a specific case.
The slide-pack covers a large variety of artificial lift methods. Explanations are supported by breakdown of pros and cons, calculations and questions. Questions will shed light of roughly how to decide which method(s) to use in a specific case.
Sucker rod pumping short course!!! ~downhole diagnosticenLightNme888
Six-page Petroleum Engineering info-graphic detailing Sucker Rod Pumping of Oil Wells and how to effectively design, operate, and optimize the well's producing efficiency. This is an amazing reference guide for anyone involved with Beam Lift as a means of Artificial Lift!!
www.downholediagnostic.com
Well Control is very important in Petroleum Engineering and necessary for being able to avoid hazards and controlling them as much as possible. This presentation provides valuable notes, instructions, and information about Well Control.
This presentation is a course a bout wellheads which includes the basic components of the well head and the advanced techniques.
helping students who are cared about petroleum industry to increase their knowledge about this tool that is important for both drilling and production.
For Further information, use the following LinkedIn account:
https://www.linkedin.com/in/mohamed-abdelshafy-abozeima-9b7589119/
Wellhead equipment Introduction Based on API 6a & NACEAmir Rafati
1. Typical Onshore Wellhead and Casing Head Types
• CSG HEAD NO.1
• CSG HEAD NO.3
• CSG HEAD NO.6
• CSG HEAD NO.8
• CSG HEAD NO.9
• CSG HEAD DESIGN DUE TO FIELD EXPERIENCES
• AG(H)-10K
• B(H)-10K
• C(H)-5K
• V(H)-5K
• T(H)-3K,5K
• WELLHEAD DESIGN DUE TO FIELD EXPERIENCES
2. Brief Description of Wellhead Equipment and their Types
• Sealings and Ring Gaskets
• Safety valves
• Gate valves
• Double Studded Adaptors
• Spools
• Hangers
• Flanges
3. Install and Testing Wellhead and Casing Head Equipment
• Safety valves
• Gate valves
• Double Studded Adaptors
• Spools
• Hangers
• Flanges
4. Introduction to API 6A applications
• PSL: PRODUCT SPECIFICATION LEVELS
• PR: PERFORMANCE REQUIREMENT
• T/C: TEMPERATURE CLASS
• M/C: MATERIAL CLASS
Presentation defines well completion as a sub-discipline of drilling operations. It introduces the various components of the well completion process. It then describes and explains basic areas of the completion process including the bottom-hole completion process, the perforation process, the upper completion with packers, tubing component equipment and devices, tubing configurations, the horizontal completions and the Christmas tree(production head)
Sucker rod pumping short course!!! ~downhole diagnosticenLightNme888
Six-page Petroleum Engineering info-graphic detailing Sucker Rod Pumping of Oil Wells and how to effectively design, operate, and optimize the well's producing efficiency. This is an amazing reference guide for anyone involved with Beam Lift as a means of Artificial Lift!!
www.downholediagnostic.com
Well Control is very important in Petroleum Engineering and necessary for being able to avoid hazards and controlling them as much as possible. This presentation provides valuable notes, instructions, and information about Well Control.
This presentation is a course a bout wellheads which includes the basic components of the well head and the advanced techniques.
helping students who are cared about petroleum industry to increase their knowledge about this tool that is important for both drilling and production.
For Further information, use the following LinkedIn account:
https://www.linkedin.com/in/mohamed-abdelshafy-abozeima-9b7589119/
Wellhead equipment Introduction Based on API 6a & NACEAmir Rafati
1. Typical Onshore Wellhead and Casing Head Types
• CSG HEAD NO.1
• CSG HEAD NO.3
• CSG HEAD NO.6
• CSG HEAD NO.8
• CSG HEAD NO.9
• CSG HEAD DESIGN DUE TO FIELD EXPERIENCES
• AG(H)-10K
• B(H)-10K
• C(H)-5K
• V(H)-5K
• T(H)-3K,5K
• WELLHEAD DESIGN DUE TO FIELD EXPERIENCES
2. Brief Description of Wellhead Equipment and their Types
• Sealings and Ring Gaskets
• Safety valves
• Gate valves
• Double Studded Adaptors
• Spools
• Hangers
• Flanges
3. Install and Testing Wellhead and Casing Head Equipment
• Safety valves
• Gate valves
• Double Studded Adaptors
• Spools
• Hangers
• Flanges
4. Introduction to API 6A applications
• PSL: PRODUCT SPECIFICATION LEVELS
• PR: PERFORMANCE REQUIREMENT
• T/C: TEMPERATURE CLASS
• M/C: MATERIAL CLASS
Presentation defines well completion as a sub-discipline of drilling operations. It introduces the various components of the well completion process. It then describes and explains basic areas of the completion process including the bottom-hole completion process, the perforation process, the upper completion with packers, tubing component equipment and devices, tubing configurations, the horizontal completions and the Christmas tree(production head)
This is a presentation series part 3 on Frequently Asked Questions on Steam Turbines in large steam power plants. All questions are answered properly and any doubt may be mailed to the writer.
TechTAC® CFD Report Summary: A Comparison of Two Types of Tubing Anchor Catcherssdickerson1
This informational report includes 1) a comparative CFD analysis of the fluid flow within the annular space around a Slimline® TAC compared to a standard TAC; 2) graphical representations of velocity, pressure drop, turbulence and vorticity; and 3) a look at the impact these factors can have on gas locking, sediment buildup, and more.
Your Score 1420Not bad. Your score means youre slightly bette.docxodiliagilby
Your Score: 14/20
Not bad. Your score means you're slightly better than the average at reading expressions. And research suggests that people can improve their emotion recognition skills with practice. So keep an eye out for our forthcoming empathy training tool, designed to boost your emotional intelligence. Sign upfor our e-newsletter for updates on it.
Drilling Engineering
Class 8
1
Casing
• What is casing?
• Pipe that is API certified for its specific application
• Why is casing set?
• Zonal Isolation when cemented in place
• Casing point selection
• Regulations
• Area Geology
• Formation Pressures
• As the operator, who decides on casing points?
2
Casing
• API casing is available in standard sizes from 4-1/2” to 20” OD
• Usually steel but can be aluminum, fiberglass, stainless steel,
plastic, titanium etc.
• One piece of casing pipe is referred to as a “joint” of casing
• Casing length is dependent on the “range” of pipe
• Range-1: 18-22ft
• Range-2: 27-30ft
• Range-3: 38-45ft
• Casing Threads are defined by the coupling type
• API Threads
• LTC: Long thread coupling
• STC: Short thread coupling
• BTC: Buttress thread coupling
• Semi & Premium Threads
• See VAM Presentation
3
Casing
• Casing Components
• Casing
• Size, Weight, Grade, Threads
• 9-5/8" 53.5# P-110 LTC Rg 3
• See Casing Data Chart
• What is Drift Diameter?
• Pup Joints
• Float Collars
• Float Shoe
• Guide Shoe
• Centralizers
• Baskets
• Scratchers/Scrapers
4
Casing
• Running Casing
• Bales/Elevators
• Power Tongs
• Torque Turn
• Calculate weight and Hookload HL
• Calculate collapse, how often should you fill the pipe?
• Is the pipe taking the proper amount of fluid to fill? CSGcap
• Is the proper amount of fluid coming back to the pits as the
casing is run in the hole? CSGcap & CSGdisp
• Once casing is landed, circulated mud. Calculate B/U
5
Casing
• Centralization
• Vertical Wells
• Never truly vertical, usually spiral
• Typically use bow spring type centralizers
• There are state regulations on centralizer placement
• The shoe is very important to be centralized
• Horizontal Wells
• Balance between too many and not enough centralizers
• Many types: rigid, floating, bow spring, bladed, spiral bladed, etc.
• Centralizer design software can model the well as drilled and suggest
centralizer placement
• High dogleg areas need more frequent centralizers to obtain
sufficient standoff
6
Casing
• Stand-off
• Pipe Stand-off is a major contributor to hole cleaning, mud
removal, and cement quality.
• % 𝑆𝑡𝑎𝑛𝑑𝑜𝑓𝑓 = ൗ𝑊𝑛 𝑅2−𝑅1 ∗ 100%
7
Casing
• Stand-off
• The Stand-off formula results a percentage, where 0% represents
the pipe in contact with the wellbore wall. 100% represents the
pipe is perfectly centered in the well.
• When the pipe is not centered, the wider portions will promote
flow due to less resistance. There can be pockets of cuttings or
mud in the tighter areas causing
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.
AUTOMATIC WELL FAILURE ANALYSIS FOR THE SUCKER ROD PUMPING SYSTEMS USING MACH...Ramez Abdalla, M.Sc
This study is a contribution to the area of fault automatic detection and diagnosis in the sucker rod pumping systems. Therefore, an intelligent system capable of detecting downhole sucker rod pumping systems problems was developed.
Diagnosis of Rod Pump Downhole Problems using Artificial Neural Networks (ANN)Ramez Abdalla, M.Sc
Rod Pump monitoring is important to sustain acceptable productivity levels. An automated system for DC shape classification is desired for quicker response avoiding production disturbances. This project proposes a method for patterns recognition based on Artificial Neural Networks, so that DCs can be better classified by the used method.
Hierarchical Digital Twin of a Naval Power SystemKerry Sado
A hierarchical digital twin of a Naval DC power system has been developed and experimentally verified. Similar to other state-of-the-art digital twins, this technology creates a digital replica of the physical system executed in real-time or faster, which can modify hardware controls. However, its advantage stems from distributing computational efforts by utilizing a hierarchical structure composed of lower-level digital twin blocks and a higher-level system digital twin. Each digital twin block is associated with a physical subsystem of the hardware and communicates with a singular system digital twin, which creates a system-level response. By extracting information from each level of the hierarchy, power system controls of the hardware were reconfigured autonomously. This hierarchical digital twin development offers several advantages over other digital twins, particularly in the field of naval power systems. The hierarchical structure allows for greater computational efficiency and scalability while the ability to autonomously reconfigure hardware controls offers increased flexibility and responsiveness. The hierarchical decomposition and models utilized were well aligned with the physical twin, as indicated by the maximum deviations between the developed digital twin hierarchy and the hardware.
CFD Simulation of By-pass Flow in a HRSG module by R&R Consult.pptxR&R Consult
CFD analysis is incredibly effective at solving mysteries and improving the performance of complex systems!
Here's a great example: At a large natural gas-fired power plant, where they use waste heat to generate steam and energy, they were puzzled that their boiler wasn't producing as much steam as expected.
R&R and Tetra Engineering Group Inc. were asked to solve the issue with reduced steam production.
An inspection had shown that a significant amount of hot flue gas was bypassing the boiler tubes, where the heat was supposed to be transferred.
R&R Consult conducted a CFD analysis, which revealed that 6.3% of the flue gas was bypassing the boiler tubes without transferring heat. The analysis also showed that the flue gas was instead being directed along the sides of the boiler and between the modules that were supposed to capture the heat. This was the cause of the reduced performance.
Based on our results, Tetra Engineering installed covering plates to reduce the bypass flow. This improved the boiler's performance and increased electricity production.
It is always satisfying when we can help solve complex challenges like this. Do your systems also need a check-up or optimization? Give us a call!
Work done in cooperation with James Malloy and David Moelling from Tetra Engineering.
More examples of our work https://www.r-r-consult.dk/en/cases-en/
About
Indigenized remote control interface card suitable for MAFI system CCR equipment. Compatible for IDM8000 CCR. Backplane mounted serial and TCP/Ethernet communication module for CCR remote access. IDM 8000 CCR remote control on serial and TCP protocol.
• Remote control: Parallel or serial interface.
• Compatible with MAFI CCR system.
• Compatible with IDM8000 CCR.
• Compatible with Backplane mount serial communication.
• Compatible with commercial and Defence aviation CCR system.
• Remote control system for accessing CCR and allied system over serial or TCP.
• Indigenized local Support/presence in India.
• Easy in configuration using DIP switches.
Technical Specifications
Indigenized remote control interface card suitable for MAFI system CCR equipment. Compatible for IDM8000 CCR. Backplane mounted serial and TCP/Ethernet communication module for CCR remote access. IDM 8000 CCR remote control on serial and TCP protocol.
Key Features
Indigenized remote control interface card suitable for MAFI system CCR equipment. Compatible for IDM8000 CCR. Backplane mounted serial and TCP/Ethernet communication module for CCR remote access. IDM 8000 CCR remote control on serial and TCP protocol.
• Remote control: Parallel or serial interface
• Compatible with MAFI CCR system
• Copatiable with IDM8000 CCR
• Compatible with Backplane mount serial communication.
• Compatible with commercial and Defence aviation CCR system.
• Remote control system for accessing CCR and allied system over serial or TCP.
• Indigenized local Support/presence in India.
Application
• Remote control: Parallel or serial interface.
• Compatible with MAFI CCR system.
• Compatible with IDM8000 CCR.
• Compatible with Backplane mount serial communication.
• Compatible with commercial and Defence aviation CCR system.
• Remote control system for accessing CCR and allied system over serial or TCP.
• Indigenized local Support/presence in India.
• Easy in configuration using DIP switches.
Immunizing Image Classifiers Against Localized Adversary Attacksgerogepatton
This paper addresses the vulnerability of deep learning models, particularly convolutional neural networks
(CNN)s, to adversarial attacks and presents a proactive training technique designed to counter them. We
introduce a novel volumization algorithm, which transforms 2D images into 3D volumetric representations.
When combined with 3D convolution and deep curriculum learning optimization (CLO), itsignificantly improves
the immunity of models against localized universal attacks by up to 40%. We evaluate our proposed approach
using contemporary CNN architectures and the modified Canadian Institute for Advanced Research (CIFAR-10
and CIFAR-100) and ImageNet Large Scale Visual Recognition Challenge (ILSVRC12) datasets, showcasing
accuracy improvements over previous techniques. The results indicate that the combination of the volumetric
input and curriculum learning holds significant promise for mitigating adversarial attacks without necessitating
adversary training.
Final project report on grocery store management system..pdfKamal Acharya
In today’s fast-changing business environment, it’s extremely important to be able to respond to client needs in the most effective and timely manner. If your customers wish to see your business online and have instant access to your products or services.
Online Grocery Store is an e-commerce website, which retails various grocery products. This project allows viewing various products available enables registered users to purchase desired products instantly using Paytm, UPI payment processor (Instant Pay) and also can place order by using Cash on Delivery (Pay Later) option. This project provides an easy access to Administrators and Managers to view orders placed using Pay Later and Instant Pay options.
In order to develop an e-commerce website, a number of Technologies must be studied and understood. These include multi-tiered architecture, server and client-side scripting techniques, implementation technologies, programming language (such as PHP, HTML, CSS, JavaScript) and MySQL relational databases. This is a project with the objective to develop a basic website where a consumer is provided with a shopping cart website and also to know about the technologies used to develop such a website.
This document will discuss each of the underlying technologies to create and implement an e- commerce website.
2. Agenda
System performance
A. Failure Analysis
(Problem Nature – Reasons – AGIBA Application)
B. Troubleshooting
(Physical Indicators – Common techniques – Common mistakes )
3. Gas Interference
PROBLEM NATURE
• Gas separated and accumulated inside the pump reducing the volumetric efficiency and in the
worst case the well stops pumping due to gas lock.
PROBLEM REASONS
• High GOR or foamy fluids .
• Poor gas venting while production.
Real Gas Interference card from Well S-66
4. Gas interfernce..cont.
Remedial Action
- Increasing the compression ratio by the following Modifications to Standard
Pumps:-
• Longer stroke length, close valve spacing & spaced low (w/o tagging) at well site
• High comp. standing valve cage
- Improve gas venting through annulus .
- Install pump below perforations to allow for gravity separation
- Install gas anchor ( separator ) .
- Use vsp (variable slippage pump ) .
6. • In Agiba applications some of the NE wells, SE, Zarif, Faras and Ramel fields are the highest gas to oil ratio
(GOR) wells (over 300 SCF/STB). In 1988 Agiba ran poor-poy type gas separator tests for two of the SE wells.
They did not show any significant improvements and this technique had some limitations:
1. It was not effective for wells producing over 300 BOPD.
2. It Impedes possible wire-line operations in the well in which it is used
Pump Intake setting below perforations
• Seating the pump intake below the perforations is the most
efficient technique if the well conditions allow it.
AGIBA applies the process for some of the Meleiha wells (M-8,
SE-6) as a trials and it was proved to be very efficient most of the
Faras, Raml and Zarif field wells.
Application of the technique created the following advantages:
• Increased pump submergance which resulted in more
production.
• Created a natural gas-separation, which improved the pumps
mechanical performance.
limitations to this technique:
Not recommended for sandy wells where pump-sticking problem
arise.
7. Fluid pound
PROBLEM NATURE :
Incomplete pump fillage creates a hammering effect for S.R.
PROBLEM REASONS :
• Insufficient pump intake pressure .
• pump intake restriction .
CAUSES SEVERE PROBLEMS LIKE :
• Pumping unit base vibration ( loosens the bolts ).
• Gear box teeth damage .
• S.R. Premature fatigue failure S.R. Premature fatigue failure .
• Rod unscrew from bottom .
• Rod buckling and excessive TBG. Wear
8. Fluid pound..cont’
Remedial Action
• Re-optimize the pumping parameters ( S.L. , SPM & P.S. ) .
• Use pump off controller to match pumping rate with the Actual well productivity .
• check pump intake for restriction ( this could be Considered in case of pounding at higher dynamic level) .
• increase pump submergence if possible .
9. Fluid pound..cont’
In Agiba Applications, The reservoir is a depletion drive type and the fast decline in reservoir
pressure was affecting the pump intake pressure. Therefore, the gas and fluid pounding problem
became a serious issue and the decrease in the dynamic fluid level consequently increased the
peak polished rod load due to increasing the net lift.
Split traveling valve cage
from fluid pound
Fractured nickel-carbide standing valve
seat from fluid pound
10. Scale deposition
PROBLEM NATURE AND REASONS
• It was observed that scale formation problems started to appear in some of the Meleiha and
Raml field wells. Chemical analysis showed that it was the calcium carbonate (CaCO3) type. Such
scale precipitates in the upper part of the tubing (surface down to about 300 ft). Presence of
scale restricted operations during pulling and running of the subsurface pump. In some cases it
created stuck pumps and then a work over was needed.
• The reasons for this problem are as follows: -
1. Pressure drop at the wellhead (below 100 psi).
2. High formation water production.
3. High temperature (over 120 F).
11. Scale deposition..cont’
• To prevent scale formation inside the well, it was found that increasing the wellhead pressure
to 150 psi would significantly improve the situation.
STUCK STANDING VALVE DUE TO SCALE
12. Sucker Rod Failures..cont’
A – TENSILE FAILURE :
• It appears as a bottle neck shape due to rod elongation when using improper rod type or creates
excessive tension to free stuck pump ,(actual applied loads tension to free stuck pump exceeds the
allowable loads ) .
B–CORROSION FAILURE :
• The rod is parted due to area reduction as a result of corrosion ( chemical reaction between steel
and CO2 , H2S OR ACID .
C – FATIGUE ( MECHANICAL ) FAILURE :
• It originates from a local increase in stress as small, progressive stress cracks that advance, upon each
applied load, with the action of fluctuating or cyclic stresses to rupture, or final shear tear.
SUCH TYPE IS CONSIDERED THE MOST COMMON TYPE WORLD WIDE .
Caused by Improper make-up, severe fluid pounding , manufacturer defects ,using old rods without
inspection , pump tagging down .
13. Sucker Rod Failures..cont’
D - ROD BUCKLING TENDENCY :
• Buckling tendency happens due to compression loads in the down stroke (the rod should be kept
under tension in all conditions ).
PROBLEMS RELATED TO BUCKLING :
• Excessive rod and tubing wear .
• sucker rod failure or unscrew .
• valve rod and valve rod guide damage .
Reasons :
• severe fluid pounding .
• excessive rod speed ( exceeds free fall speed ) .
• heavy viscous oil .
• improper rod string design .
• pump tagging .
14. Sucker Rod Failures..cont’
ROD BUCKLING TROUBLESHOOTING :
• Eliminate pounding and optimize speed specially in heavy viscous wells
• Use sinker & stabilizer bars to centralize rods and keep in tension .
• Never keep pump strongly tagging down .
CORROSION TROUBLESHOOTING :
• Use corrosion resistant rod type .
• use corrosion inhibitor
MAX TENSILE TROUBLESHOOTING :
• Better rod type selection during the initial design .
• Never exceed the allowable rod load rating during trials to free stuck pump .
FATIGUE TROUBLESHOOTING :
• Re-optimize the well pumping parameters to minimize fluid pounding .
16. Heavy Oil
• Characteristics of Aghar Field Heavy Oil
- API 10-17
• PCP Vs. S/R System in Aghar Field
- Limited ability to increase the PCP parameters
- Limited well accessibility
• Applying S/R Systems in heavy oil wells
- Small Pumping Units
- Slow pumping rate Real Viscous oil problem from Well AG 4-13
17. Sand Production
PROBLEM NATURE
• When Producing Sand Up through your Production Tubing, Separation Will occur. The Heavier, More
Abrasive Sand, Will Settle Back On Top Of The Rod Pump. The Smaller, Less Abrasive Sand Will Stay
Suspended, And Be Lifted To The Surface. The heavier sand will brake up to small pieces and be carried
between the plunger and barrel.
PROBLEM REASON
• The sand particles will work their way between the Barrel and the plunger, causing abrasion cuts ,
commonly known as “sand cutting”.
• Sand Friction causes rod buckling resulting in failures.
18. Sand Production..cont’
• Two origins in AGIBA
- Formation sands/fines
- Hydraulic fractured Wells sands / propants
• Effect of sand on the total production system
- Sand friction cause rod buckling
- Abrasion/wear for the plunger “Sand Cut”
Wear of Plunger caused by sand production
Sand Cuts
20. Stuck pumps
In AGIBA application stuck pumps which existed
only in the Bottom Hold-Down type. This BHD
creates the possibility of sand & debris
accumulating in the dead area between the
pump and the tubing wall.
Such problems was overcome by introducing the
Top Hold-Down pump instead of bottom hold
down.
21. Tubing Wear
PROBLEM NATURE
Tubing failures had longitudinal cracks with an average length of 10 ft. and all the cracks were in
the lower part of the tubing ( up to 500 ft above the pump seating nipple). This tubing interval
was located against the sinker bar portion of the sucker rod string.
• IT IS CONSIDERED AS ONE OF THE COMMON PROBLEMS OF S.R. System world-wide .
TBG. Wear due to rod buckling
22. TBG. Wear ..cont’
PROBLEM REASONS :
• Rod buckling (high speed , insuffecient sinker bar , fluid pounding , pump
tagging down ) .
• Tubing buckling (unanchored tubing or apply insufficient tension ) .
• Use sucker rod system in crooked holes .
• Free water production (represents the main critical reason Since it increases
mutual friction between rods and tubing ) .
• Presence of corrosive fluids ( enhances the erosion corrosion effect )
23. TBG. Wear ..cont’
HOW TO MINIMIZE TUBING WEARS AND CRACKS :
• Eliminate all reasons of rod buckling .
• Apply proper tension for tbg. String ( use KTH hanger ) .
• Use rod guides or wheel guides to centralize rods inside tubing .
• Use anti-friction couplings and blast joints in the hot spots .
• Apply corrosion inhibition programs .
• Minimize pumping speed .
24. WELL
NO. OF W/O DUE
TO TBG LEAK
per year
M-29 3
M-42 3
A-6 3
A-46 3
NE-36 3
M-43 3
M-57 3
A-4 5
NE-14 3
NE-25 3
SE-4 3
E-1X 3
N.NADA-8 3
FALAK-11 3
M-14 3
A-41 3
WELLS FREQUENTLY SUFFERED FROM TBG LEAK
NE-32 2
NE-43 2
M-SW-2 2
SE-20 2
FALAK-7 2
A-37 2
Z-27 2
M-33 2
M-50 4
M-18 4
M-34 4
M-37 4
M-47 4
M-52 3
A-25 3
Z-15 3
M-49 3
• The main problem lead to workover jobs in AGIBA is the tubing leak , which appears in
the form of longitudinal cracks as 2 ft length × 2cm width, caused by contineous friction
between sucker rod and internal tubing wall , especially at the last ten joints ( 300 ft )
right above the pump.
25. Rod Guides
Spiral metal guides were tested in AGIBA fields. The
experience proved that it was not an effective solution for
this condition due to the following difficulties:
a. It required fixed regular schedules for round trips to
replace the worn-out guides.
b. The installing of rod guides created much more
friction, which increased the loads and stresses in the
sucker rod string and the possibility of rod failure.
Due to high loads, there was no way to increase pumping
parameters in order to increase production.
- Valve rod guide worn-out
Due to buckling
- Metal to Metal contact
- High friction
26. Hollow Pump
WELL
PERIOD BETWEEN LAST W/O
& FIRST TBG LEAK
M-14 8 MONTHS
M-37 1 YEAR
M-47 7 MONTHS
A-4 11 MONTHS
A-5 6 MONTHS
A-34 9 MONTHS
FIELD TRIALS (HOLLOW PUMP)
Hollow sucker rod has hole in the middle
The smaller passage and the faster flow velocity can avoid the sand
deposit efficiently while use hollow sucker rod in the sand well.
27. WELL Rate W/C
PERIOD BETWEEN LAST
W/O & FIRST TBG LEAK
E - 1X 215 45 9 MONTHS
M - 37 80 55 6 MONTHS
- Using of roller guide or wheel guide , to eliminate direct contact between sucker rods and internal tubing wall.
- Applying of a KTH flange gives more tension for tubing with slips to prevent tubing buckling.
29. Physical Trouble Shooting Indicators
- Pressure Gages
- Hot Flow Lines
- Hot Polished Rod Load
- Sounds at the Well
- Equipment Vibrations
- Fluid on the Ground
- Ground Shakes
30. Well Head Temperature As A Relation Of Production Rate
(GOR From Zero Up To 100 Scf/Stb)
Well head temperature, oF
Productionrate,bpd
Zero water cut
Zero up to %water cut
up to %water cut
up to %water cut
31. common Techniques for Trouble Shooting
- Has Well’s Production Changed?
- Can the Pump Pressure up the Tubing?
- Is the Pumping Unit Running?
- Is there a noticeable Leak?
- Is fluid going into the tank?
- Has the Fluid Level Changed?
32. Not Recommended
- Why are not we tagging?
- Put on hand and Pump 24 hrs/day.
- Increase SPM in Order to maintain Production.
- Increase SPM because there is a Fluid Level Above the Pump.
- Pull the Well, because no Fluid in the Tank.