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NP_GX34_MI Drilling Program_WDI-840 NP_GX34_MI Mishrif Producer NORTH RUMAILA RIG: WDI-840 Halliburton Consulting and
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NP_GX34_MI Drilling Program_WDI-840
NP_GX34_MI Mishrif Producer NORTH RUMAILA RIG: WDI-840
Halliburton Consulting and Project Management
1
NP_GX34_MI Drilling Program_WDI-840
Approvals Halliburton Worldwide Limited
Produced by:
Signature and Date
Senior Drilling Engineer, CPM Iraq
Reviewed by: Senior Drilling Engineer, CPM Iraq
Drilling Superintendent, CPM Iraq
Approved by: Project Manager, CPM Iraq
Rumaila Operating Organization (ROO)
Reviewed by:
Signature and Date
TK Senior Drilling Engineer TK Drilling Team Lead Drilling Superintendent Drilling Engineering Manager NWD Manager Drilling Manager
Approved by: Wells Manager
2
NP_GX34_MI Drilling Program_WDI-840
Document Control Rev No.
Date
List of Changes
Author
0
08/28/2017
Draft Document Creation
HT
3
NP_GX34_MI Drilling Program_WDI-840
Distribution List Position Halliburton Ops Manager Halliburton Project Manager Halliburton Drilling Superintendent Halliburton Sr. Drilling Engineer Halliburton Drilling Engineer Halliburton Rig DSV Rig Tool Pusher WPS/ Halliburton Baroid/ Halliburton Cement/ Halliburton Sperry/ Halliburton ROO Drilling Manager ROO Drilling Engineering Manager ROO TK Sr. Drilling Engineer ROO Drilling Superintendent ROO TK Drilling TL ROO DSV ROO Geologist TL ROO Well site Geologist
Hard Copy
Soft Copy × × × ×
× × × × × × × × × × × × × × ×
Company Halliburton Halliburton Halliburton Halliburton Halliburton Halliburton WDI Halliburton Halliburton Halliburton Halliburton ROO ROO ROO ROO ROO ROO ROO ROO
Glossary of Terms Term Azimuth Back-Pressure Valve Balanced Cement Plug Blowout Preventer Bottom hole Assembly Casing Head Housing Circulation Sub Daily Drilling Report Distinct Permeable Zone Double-Studded Adapter Drilling Supervisor Drill-Off Test Dropped Object Awareness and Prevention Equivalent Circulating Density Hook Load Inclination Kick-off Point Lost Circulation Material Low-Energy Drilling Operation Management of Change Mud Weight
Abbreviation AZI BPV BCP BOP BHA CHH PBL DDR DPZ DSA DSV DOT DROPS ECD HKLD Incl. KOP LCM LEDO MOC MW, ECD 4
NP_GX34_MI Drilling Program_WDI-840 Multi-Bowl Wellhead System Multi-Stage Inflatable Collar Packer Personal protective equipment Plastic Viscosity Plug-Back Total Depth Rate of Penetration Revolutions per Minute Security and Safety Compliance Officer Security Plans Officer Solids Control Equipment Stage Collar Strokes per Minute Sustained Casing Pressure Top of Cement Top-Drive System Total Flow Area True Vertical Depth Measured from Mean Sea Level True Vertical Depth Measured from Rotary Table Tubing Head Adapter Tubing Head Spool Tungsten Carbide Insert Two-Way Check Valve Umm Er Radhuma Upper Casing Spool
MBS MSICP PPE PV PBTD ROP RPM RSSCO SPO SCE DV SPM SCP TOC TDS TFA TVDMSL, TVDSS TVDRT THA THS TCI TWCV UER UCS
STANDARD OF UNITS Parameter Annular Speed Casing Weight Density, Mud Weight, ECD Depth, Length, Height, Distance and Elevation Flow Rate H2S Amount Hole, Bit and Tool Sizes Angle Hook Load Pressure Rate of Penetration Temperature Torque Total Depth Total Flow Area Volume Weight on Bit
Unit m/min. lb/ft, lbm/ft s.g. m lpm ppm in. degree Klbs psi m/h °C lb-ft, lbf-ft m sq. in., in.2 L, m3 Klb
5
NP_GX34_MI Drilling Program_WDI-840
Table of Contents 1.0
INTRODUCTION ........................................................................................................................................... 10
2.0
MANAGEMENT OF CHANGE POLICY ........................................................................................................... 10
3.0
HSE ............................................................................................................................................................... 11
3.1
Safety Systems ......................................................................................................................................... 11
3.2
Frequency of Safety Drills ........................................................................................................................ 11
3.3
ROO Golden Rules.................................................................................................................................... 12
3.4
Halliburton Life Rules ............................................................................................................................... 12
3.5
Halliburton Emergency Contacts ............................................................................................................. 12
3.6
ROO Emergency Medical Contacts .......................................................................................................... 13
4.0
ROO STANDARDS......................................................................................................................................... 13
5.0
MATERIALS AND LOGISTICS ........................................................................................................................ 13
6.1
Surface Location and Target Data............................................................................................................ 14
6.2
Well Objectives ........................................................................................................................................ 14
6.2.1 Strategic..................................................................................................................................................... 14 6.2.2 Technical.................................................................................................................................................... 14 6.2.3 Reservoir Pressure and Temperature Prognosis ....................................................................................... 15 6.2.4 Reservoir Parameters and Fluid ................................................................................................................ 15 6.3
Well Schematic Casing and Cementing ................................................................................................... 16
6.4
Target Tolerance ...................................................................................................................................... 17
6.5
Well Location ........................................................................................................................................... 18
6.6
Offset Well Locations ............................................................................................................................... 19
6.7
Offset Well NPT Summary ....................................................................................................................... 19
6.8
Distinct Permeable Zones ........................................................................................................................ 20
7.0
GEOLOGICAL INFORMATION ....................................................................................................................... 21
7.1
Mud Weight Window............................................................................................................................... 21
7.2
Geological Prognosis ................................................................................................................................ 23
7.3
Reservoir Analogue – Offset Well Data ................................................................................................... 24
7.4
Formation Tops ........................................................................................................................................ 25
8.0
ZONAL ISOLATION CRITERIA ....................................................................................................................... 26
9.0
DIRECTIONAL PLAN AND SURVEY PROGRAM ............................................................................................ 27
9.1 Well Trajectory Plot and Plan View ............................................................................................................. 27 9.2
Directional Survey Plan ............................................................................................................................... 28
9.3 Well Trajectory Plan ..................................................................................................................................... 29 9.4 10.0 10.1
Anti Collision Summary Report................................................................................................................... 32 WELLHEAD AND BOP STACK CONFIGURATION .......................................................................................... 36 17 ½” Hole Section ................................................................................................................................... 36 6
NP_GX34_MI Drilling Program_WDI-840 10.2
12 ¼” and 8 ½” Hole Section .................................................................................................................... 37
10.3
Completion Phase .................................................................................................................................... 38
10.4
BOP Equipment Pressure Test ................................................................................................................. 39
11.0
OPERATIONS BREAKDOWN......................................................................................................................... 40
12.0
PRE-SPUD OPERATIONAL CHECKLIST .......................................................................................................... 44
12.1
Rig Acceptance Checklist ......................................................................................................................... 44
12.2
Pre-Spud Checklist ................................................................................................................................... 45
13.0
26” HOLE SECTION (0 m – 43 m) ................................................................................................................. 46
14.0
17 ½” HOLE SECTION (43 m – 613 m) .......................................................................................................... 46
14.1
Drilling Risk and Mitigation ...................................................................................................................... 46
14.2
Preparation .............................................................................................................................................. 47
14.3
17 ½” Hole Drilling Procedure.................................................................................................................. 47
14.4
17 ½” BHA Program ................................................................................................................................. 48
14.5
17 ½” Bit Program .................................................................................................................................... 49
14.6
Mud Properties – Gel polymer – 17 ½” section ....................................................................................... 49
14.7
17 ½” Directional Control ........................................................................................................................ 50
14.8
13⅜" Casing Information (Setting Depth +/- 611m) ................................................................................ 50
14.9
Running 13 ⅜” Casing .............................................................................................................................. 50
14.10 Cementing 13 ⅜” Casing .......................................................................................................................... 52 14.11 Installing Wellhead (Slip-Lock, CHH and UCS) ......................................................................................... 56 15.0 12 ¼” HOLE SECTION (613m – 2037m) ......................................................................................................... 61 15.1
Drilling Risk and Mitigation ...................................................................................................................... 61
15.2
Preparation .............................................................................................................................................. 62
15.3 12 ¼” Hole Drilling Procedure .................................................................................................................... 62 15.4
12 ¼” BHA Program ................................................................................................................................. 65
15.5
12 ¼” Bit Program .................................................................................................................................... 66
15.6
Directional Program ................................................................................................................................. 66
15.7
Mud Program – 12 ¼” section ................................................................................................................. 66
15.8
12 ¼” Logging Program ............................................................................................................................ 67
15.9
9 ⅝" Casing Information (Setting Depth: ~ 2035mMD)........................................................................... 68
15.10 Running 9 ⅝” Casing ................................................................................................................................ 70 15.11 Installing 9 ⅝” Mandrel Casing Hanger ...................................................................................................... 72 15.12 Cementing 9⅝” Casing ............................................................................................................................. 73 15.13 Jetting Wellhead ...................................................................................................................................... 79 15.14 Installing 9 ⅝” Casing Hanger / Pack-Off ................................................................................................. 81 16.0 16.1
8 ½” HOLE SECTION (2037mMD – 2498mMD) ........................................................................................... 85 Drilling Risk and Mitigation ...................................................................................................................... 85 7
NP_GX34_MI Drilling Program_WDI-840 16.2
Preparation .............................................................................................................................................. 86
16.3 8 ½” Hole Drilling Operations ..................................................................................................................... 87 16.4
8 ½” BHA Program ................................................................................................................................... 89
16.5
8 ½” Bit Program ...................................................................................................................................... 89
16.6
8 ½” Directional Program......................................................................................................................... 89
16.7
Mud Program - KCL Polymer for 8 ½” Section ......................................................................................... 89
16.8
8 ½” Logging Program .............................................................................................................................. 91
16.9
7” Casing Information (Setting Depth: ± 2496m) .................................................................................... 92
16.10 Running 7” Casing .................................................................................................................................... 94 16.11 Installing 13 ⅝” x 7” MBS Casing Hanger ................................................................................................. 95 16.12 Cementing 7” Casing ................................................................................................................................ 96 16.13 Installing Pack-Off Seal Assembly ............................................................................................................ 99 16.14 7” Cased Hole log ................................................................................................................................... 101 17.0 COMPLETION OPERATIONS / WELL SUSPENSION OPERATIONS ................................................................. 102 17.1 Preparation Running 3 ½” Tubing String .............................................................................................. 102 17.2 Running 3 ½” Tubing String ..................................................................................................................... 102 17.3 Install 11” x 3 ½” Tubing Hanger ............................................................................................................. 103 17.5 Install 11” Tubing Head Adapter (THA) .................................................................................................... 104 17.6 Install Christmas Tree ............................................................................................................................... 104 17.7 Well Location Checklist ............................................................................................................................ 105 18.0 APPENDICES ................................................................................................................................................... 106 18.1
A1 − Pressure Testing Requirements ..................................................................................................... 106
18.2
A2 − Connection Best Practices ............................................................................................................. 107
18.3
A3 − Borehole Cleaning and Tripping Best Practices ............................................................................. 109
18.4
A4 − Stuck Pipe Worksheet .................................................................................................................... 112
18.5 Sentinelcem Plug strategy .......................................................................................................................... 113 18.6
A5 − Dammam Lost Circulation Strategy ............................................................................................... 114
18.7
A6 − Hartha Lost Circulation Strategy .................................................................................................... 118
18.8
A7 − Hartha Cement Plug Considerations.............................................................................................. 119
18.9
A8 − Rig-Site Guidelines for Cleaning and Visual Inspection of Casing/Tubing Threads ....................... 120
18.10 A9 – Decision Tree for Running & cementing 9 5/8” Casing. ................................................................ 122 18.11 A10− Wellhead and X-mas Tree Orientation ......................................................................................... 125 18.12 A11− Well Control Action Plan ............................................................................................................... 126 18.13 A12 − Wellhead Details & Running Tools ............................................................................................... 127 18.15 A13 − RACI Chart ...................................................................................................................................... 133 18.16 A14 − Offset Wells Lessons Learnt ......................................................................................................... 134 18.19 A15 − FIT Requirements ......................................................................................................................... 180 8
NP_GX34_MI Drilling Program_WDI-840 18.20 A16 – Mishrif/Main Pay Producer/Injector Wells (17 ½” Section TD decision Tree) ............................. 184 18.21 A17 - Contact List ................................................................................................................................... 185 18.22 A18 ROO Contact List ............................................................................................................................. 186
MOC LOG This following table is to be filled on well site by Halliburton Drilling Supervisor capturing Management of Change documents issued during operations.
MOC No.
Date
Subject
Reference Section
Comments
9
NP_GX34_MI Drilling Program_WDI-840
1.0
INTRODUCTION
The objective of this specific document is to provide a program and detailed procedures for drilling NP_GX34_MI well in accordance with the ROO and Halliburton policies, procedures and best practices. This document contains the necessary operational steps and reference technical information specific to the well. NP_GX34_MI well is a Mishrif Producer situated in North Rumaila field. The well is to be drilled as S-Shape Well (Type 3) with planned TD of -2,352.90m TVDSS, 2,447.54mMD BRT and 2,371.20mTVD BRT.
2.0
MANAGEMENT OF CHANGE POLICY
At times, it is necessary to make changes to approved program; however failure to follow the program might also have adverse results. The following describes the process of amending the final program so that the work is always conducted in an approved manner. Program Generation and Maintenance 1. 2. 3. 4.
5. 6. 7. 8. 9. 10. 11.
12.
Drilling Engineer is responsible for preparing this program which is issued for every well drilled. The author has had sufficient time to thoroughly research and complete a good program without time pressure. The programs have been reviewed in a controlled environment, typically by risk assessment by peers, including field supervisors. The rotation system may not allow everyone to review the program before publishing, and the person who supervises the work may or may not have reviewed the program before it is published and the work starts. The program has been reviewed by the ROO. Programs occasionally are published with errors or potential improvements where changes could be made. For this reason, Program amendments shall be issued under the MOC procedure. Programs shall be followed unless an amendment is approved. Programs shall be distributed as per approved distribution list. The approved drilling program is a controlled document. Any team member who sees a potential problem or improvement can and should suggest an amendment. Request for an amendment normally comes directly from the DSV to the Drilling Superintendent, preferably after being discussed at the rig site. Program amendments shall be issued under the MOC procedure. All significant changes to the program will come via written approval from the Drilling Superintendent. These program changes must be documented, risk assessed and then sent through the program approval process. The following must be considered: a. What can go wrong with or without the changes? b. What contingency materials and personnel must be considered? c. What implications on material stock does this have for upcoming wells? d. What financial benefits are there with or without the change?
10
NP_GX34_MI Drilling Program_WDI-840
3.0
HSE
The HSE objectives of this well are as follows: 1. Zero injuries, and 2. Zero environmental impact. To help achieve these objectives the following must be adhered to: 1. Personal protective equipment (PPE) must be worn at all times for all personnel on location. 2. The drilling contractor is to make sure a rig move plan is in place prior to any rig move. Make sure all overhead power lines are identified with a large warning sign. 3. Be aware that fire can start quickly in all atmospheric conditions and precautions should be taken when handling flammable materials and chemicals. 4. Dangerous chemicals are to be stored in a segregated area with clearly markings. 5. Be certain the correct size slings are used when lifting heavy loads. Watch for wear on slings and cables and remove from use if excessive wear is evident. Ensure all slings, lifting equipment have up to date certifications. Always use shackles with safety pins. Lifting gear color code points (certified + Paint). 6. Care should be taken to avoid spills, especially gasoil and crude oil. All spills should be reported and cleaned up as soon as possible. WDI to build barriers round diesel tanks. 7. Seat belts should be used and speed limits obeyed at all times during personnel transportation. 8. Prior to handling of any explosives on-site, conduct full disclosure tailgate safety meeting complete with participant signatures informing location personnel of entire perforating process including radio silence, mobile phones are to be switched off and locked up for the duration and shut-down of electrical generation except for required power supply. Unauthorized personnel are not allowed in the vicinity while arming. 9. All incidents, accidents and near misses are to be reported, recorded and investigated. 10. Implement and use safety programs and processes including Stop Card program, HSE Policy Awareness, PJSM and Toolbox Talk. 3.1
Safety Systems
All rig safety systems shall be fully operational, calibrated and maintained according to manufacturer’s guidelines. 3.2
Frequency of Safety Drills
The following table summarizes the frequency of all safety drills:
Drill
Frequency
Kick / BOP drill and when in casing Spill Man Down H2S Fire Security Choke drill
Weekly Weekly Weekly Weekly Weekly Every two weeks Before drilling each casing shoe
11
NP_GX34_MI Drilling Program_WDI-840 3.3
ROO Golden Rules
ROO’s “Golden Rules” are listed as follows: 1. 2. 3. 4. 5. 6. 7. 8.
3.4
Getting the basics right; Permit to work; Confined space entry; Driving safety; Energy isolation; Ground disturbance; Lifting operations; Working at heights.
Halliburton Life Rules
Halliburton’s “Life Rules” are listed as follows: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10.
Driving Safety; Work Permit; Proper PPE; Lock out – Tag out; Confined Space; Working at Height; Chemical Handling; Dropped Objects; Hand Tools; Lifting and Hoisting.
Halliburton applied inside PSLs each one of the Life rules and uses them in daily work. 3.5
Halliburton Emergency Contacts
Position Country Security Manager − Emergency
Medic (On Call 24 hr.)
Phone Number +964 (780) 912 5384 +964 (780) 912 5384 88 531 4666 +964 (780) 912 4975 +964 (780) 913 2907
E-mail [email protected] [email protected]
12
NP_GX34_MI Drilling Program_WDI-840 3.6
ROO Emergency Medical Contacts
Position
Phone Number
ROO SCCC HQ Emergency
+964 780 497 0677 +44 207 048 8555 +964 770 492 9620 +44 207 374 2225 +44 207 374 2204 +964 770 492 9574 +44 207 048 8425
Medic (On Call 24 hr.)
Doctor (On Call 24 hr.)
4.0
E-mail
[email protected]
[email protected]
ROO STANDARDS
The following ROO minimum standards and policies should be followed for all operations. Updated soft copy of all policies must be available in the DSV office. It is the obligation of the DSV to ensure that all documents are present. This program requires several procedures to be conducted according to the latest ROO standards. In each case, a reference is made to the appropriate ROO standard. The following is a list of ROO standards available at the time of publication:
1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15.
5.0
Rumaila Minimum Drilling Standard; Well Control Emergency Response Plan Rumaila Operating Organization; Rumaila Minimum Standard for Well Control Practices; Rumaila Minimum Standard for Key Well Control Document and Drills; Rumaila Minimum Standard – Barriers for Breaking Containment; Rumaila Wells Minimum Zonal Isolation, Temporary and Permanent Abandonment Standard; Rumaila Minimum Standard for Pressure Testing; Rumaila Wells Minimum Standards for Wireline and TCP Perforating; Rumaila Wells Minimum Standard for Hydrogen Sulfide and Hazardous Materials in Well Operations; Rumaila Wells Minimum Standard Directional Drilling & Survey; Rumaila Wells Minimum Standards for Drilling Fluids; Rumaila Minimum Standard for Cementing; ROO Pumping Operating Standard; Rumaila Well Integrity Management Standard; Rumaila Wells RA Source Abandonment Standard.
MATERIALS AND LOGISTICS
The process for equipment movements either to the rig or from the rig commences at the rig site. The DSV is responsible for ensuring that ‘call-off’ sheets are generated well in advance to account for any delays. The single point of contact for materials & logistics in the ROO drilling office is the ROO TK TL and ROO DMCL. Halliburton Drilling Superintendent will liaise with ROO TK TL for any material and logistics issues. The DSV is responsible for tracking rental equipment, ensuring the correct equipment arrives and departs on time, is loaded in a safe manner and is fully certified with up to date certificates.
13
NP_GX34_MI Drilling Program_WDI-840 6.0
GENERAL WELL DATA
6.1
Surface Location and Target Data
Contractor/ Rig GL – MSL Elevation RT-GL Elevation RT-MSL Elevation Cellar Depth Well Profile Grid Surface Coordinates System Surface Coordinate Target Reservoir Target Formation and Depth Target Coordinates Target tolerance and Shape TD formation and Depth
6.2
Weatherford WDI-840 2.70 m 7.80 m 10.50 m 2.5m [All wellhead measurements are to be taken from ground level] Type-3, Mishrif Well (Well to be completed as Mishrif Producer with 3 1/8” Xmas tree) WGS84 UTM Zone 38N 722825.80m E; 3382538.30m N Primary Target: Mishrif Mishrif Formation -2,213.30 mTVDss, 2,231.60 mTVDBRT 723185.70m E; 3382811.00m N 25 m radius circle, centred on at the Target Coordinates Rumaila Formation -2,352.90 m TVDSS, 2,447.54 m MDBRT and 2,371.20 m TVDBRT
Well Objectives
Well NP_GX34_MI is a Mishrif Producer well situated in North Rumaila. The well is one of 9 wells in an inverted spot pattern that are essential to meet the long term production forecast. 6.2.1 Strategic Following are the technical objectives for this well;
To deliver a production well at the edge of the water flood front produced by the offset injectors (when on production these wells will allow the time to water break through to be determined and the water cut development profile to be characterized) To characterize the fluid saturations, pressure variability and reservoir heterogeneity of the Mishrif reservoir. Within the expected well life the well shall be converted to serve as a water injector in line with the current Mishrif depletion plan. This conversion will be subject of a separate SOR.
6.2.2 Technical Following are the technical objectives for this well;
To deliver a Mishrif production well. To obtain open hole logs and cuttings in order to provide information of non-reservoir intervals penetrated in the well. To inform the perforation recommendation.
14
NP_GX34_MI Drilling Program_WDI-840 6.2.3 Reservoir Pressure and Temperature Prognosis Pressure (psi) Most likely 2820 2640 -
Formations mA mB1 mB2
Mishrif (North)
Temperature Most likely ~75° C (Initial Res temp) ~75° C (Initial Res temp) -
6.2.4 Reservoir Parameters and Fluid Reservoir Subzone
mA mB
Thickness Mean(m)
Porosity
56.2 76.8
0.1-0.25 0.1-0.25
Net to Gross
Not estimated
Net Permeability kh(mD)
0.01-200 0.01-200
Fluid contacts No free water expected
15
NP_GX34_MI Drilling Program_WDI-840 6.3
Well Schematic Casing and Cementing
16
NP_GX34_MI Drilling Program_WDI-840
6.4
Target Tolerance
The well has been planned as Type 3 (D5) – S-Shape well and the target tolerance is 25m Radius circle centered on target coordinates. The target limits are explained in the below diagram. It must be ensured that the well should not be outside of these coordinates at any time while drilling from top reservoir to TD to maintain the well spacing. Geological target tolerances 25m Radius are depicted in the following diagram.
Graphical presentation of target tolerance
17
NP_GX34_MI Drilling Program_WDI-840 6.5
Well Location
18
NP_GX34_MI Drilling Program_WDI-840 6.6
Offset Well Locations
The offset database shows numerous events in surrounding wells which may pose a risk whilst drilling this target location. The table below summarizes these risks and highlights nearby wells ( 60 bbl/hr NO
Continue drilling and pump 40-60 ppb LCM pill every single drilled
NO
A
Continue Drilling as per plan YES
A Down hole losses NO
YES
*2nd SentinelCem plug
losses > 60 bbl/hr YES
Continue drilling and pump 40-60 ppb LCM pill every single drilled
1
113
NP_GX34_MI Drilling Program_WDI-840 18.6
A5 − Dammam Lost Circulation Strategy
Total Dammam Lost Circulation Mitigation Strategy Cement plug volume 2b – With Total Losses > 15 m3/hr Dynamic
Cement plug volume 2a – With Partial Losses < 15 m3/hr dynamic
LCM as per LCM strategy
DAMMAM LOSSES
YES b f
f
h. b
h.
”
SentinelCem Volume vs Losses Rate
Review SentinelCem Volume vs Losses Rate table, and identify volume required to be used. Pump through BHA SentinelCem as per program.
D b
-
NO NO
h
h h
h
YES ”
D b
-
Evaluate static losses rate while WOC.
h h
. -h
YES
h
-bb h ,
h
NO
Drill Dammam: WOB: 10 - 15 Klb – RPM: 80-100 – ROP: 10 - 15 m/hr – Flow: 1600 – 1800 lpm
YES
f
Partial losses observed. POOH OEDPs to 250m b casing shoe and W .D f h annulus
YES
f
NO NO
Drill out Cement Parameters: ” D h the annulus.
” D h the annulus. POOH
POOH
WOB: 5 Klb – RPM: 80; ROP: 8-10 m/hr. – Flow: 1600 lpm
W
.D
f
W
.D
f
After cement plug: a) Circ to check losses after reach 50psi compressive strength of cement plug b) In case of losses are continued: set 2nd / 3rd cement plug c) In case of no-losses: D , Tag with bit (open nozzles) and drill when reached 100 psi compressive strength
2a
RIH with ” OEDP and tag TOC with 10m3 to strengthened the harhta prior to cement job Make sure that annulus is full of mud in case of losses as 7 bbl lost in annulus without filling the hole will bring - in Tayarat and along with losses in hartha cross flow will start and cement jobs will result in failure.
High pressure while circulate and condition mud prior to cement 7” casing
R-593
bump the plug and then while opening the DV tool.
135
NP_GX34_MI Drilling Program_WDI-840 R-593
R-593
2nd Stage Top Plug not bumped and Twice displacement volume
Closing Plug Length (11.25 in) is larger than Plug container space between the two plungers (10.4 in) ,So if top plunger Closed it will press the top of Closing Plug wipes. Closing Plug Max OD (9.0 in) is smaller than Plug Container ID (9.8) which leave chance to plug to lean on one side Total displacement (64.65 + 64.2 = 128.85 m3 ) and theoretical Displacement should be 64.5 m3
DSV to ensure that whenever closing Plug have been preloaded on BTM Plug Container Plunger ,Do not Close the top Plunger After Drop Closing Plug Release pressure ,Knocked off Plug container lifting swivel and Physically check the top/Closing Plug using T-bar” Change in plan for over displacement should follow Management of change process.
While logging 9 5/8'' casing with CAST logging tools, observed uncertainty in CAST data, ReRun the CAST log
CAST log centralizers confirgation was not correct. POOH and changed the centralizers configuration and RE-run the log.
WPS to confirm that all runs configurations are standardized same as with previous successful runs
Use the bypass adaptor above the float collar 2 joints above the float shoes, the baffle adaptor is to be placed one joint above float collar
To be shared with client and other projects
9 5/8" casing cementing
In two previous wells 9 5/8" casing jobs, decided as preventive action to uses bottom plug in the form of bypass plug this is helping with wiping down the mud film on the interior of the casing and helps to prevent the contamination of cement in the shoe track and around the shoe While drilling Shuiaba and upper shale formation, observed high torque of 18~19klbs.ft and frequent string stalling and very low ROP, tried to perform wiper trip, change parameters without success.
POOH to surface found the bit and motor in very good condition. changed the bent housing from 1.22° to 0°, reduced the number of HWDP below the jar from 21 to 15, RIH back to bottom, torque off bottom and on bottom reduced and could drill to TD without problems. In case of high torque in this type of wells (the same incident was recorded in Ru-018A which has the same well type with inclination of 32°) while performing wiper trip on top of Zubair, continue to POOH to surface and change
To be communicated and shared with other projects
R-596
R-596
Drilling in Shuiaba and Zubair with high torque
DSV to ensure that Physically check the top/Closing Plug using Tbar. Any change in plan to follow Management of change process.
WPS to ensure that tool configuration are comminuted to CPM
136
NP_GX34_MI Drilling Program_WDI-840 the bent housing R-596
Wiper trip and running 7" Casing
After the 3rd log of WL performed wiper trip at 3442m, 5m of fill was recorded, washed down and pumped 4m3 of heavy pill of 1.35sg, and circulated hole clean. POOH freely. As result of this good hole condition, running casing went very smooth without any tight spot, intermediate circulations resulted with normal pressure. Tagged the bottom at 3447m (TD), circulation at bottom resulted of normal pressure stabilized at 1250psi @1000lpm, cementing operation went smooth without high pressure
Cementing 13 3/8" casing
In this well, cement volume excess used in cementing program was 120%, while displacement with first 50bbl observed spacer received at surface, then recorded 200bbl of cement return which is approximatively the volume of lead
In next well reduce the cement volume excess to 100% to prevent having much returns at surface
Drilling 12 1/4" In Hartha
While drilling Hartha formation with rotary packed BHA, observed Slow ROP of 2~4m/hr in formation dominated by dolomite, tried to change the parameters, the bit was giving the same performance. Decided to POOH to check the bit, found the bit damaged and ring out, dull grading: 2-4-DL-S-X-IRO/HC-PR.
investigation showed that this damage was due to high temperature and was caused by reducing the FR to 1500lpm at top of Hartha which reduced the HSI, there was not enough flow to cool down the bit. the flow rate is normally reduced while drilling Hartha formation to reduce the ECD and avoid inducing losses in the same formation.
While Pulling out with directional BHA, observed tight spot in Sadi formation, had to backream (hard back ream recorded), Gyro was not dropped prior POOH. Offset wells showed tight
Be careful when reaching Sadi and monitor closely the drag, if necessary perform backreaming carefully. Do not drop Gyro until a trip out is performed or wiper trip to shoe is done, making sure that
R-600
R-600
R-600
Backreaming in Sadi
Using the heavy pill helped to clean effectively the well and provided hole in very good condition to run and cement 7", keeping in mind the shape of the hole and history of last wells where high pressure were recorded while circulating at bottom and cementing.
Including the use of heavy pill to sweep the hole at the last wiper trip before running casing
To be implemented in next wells
In the next well, the flow rate in Hartha should not be reduced below 1700-1800lpm, this is meant to have good HIS and ensure the cooling of the bit to avoid damage caused by heat. To be communicated and implemented in next wells
To be communicated and implemented in next wells
137
NP_GX34_MI Drilling Program_WDI-840
R-534
Unable to get sufficient build up rate while drilling 12¼” section
hole and back reaming was performed in north and south Rumaila.
Sadi is passed and conditioned. Preferably Drop gyro on the last wiper trip before running 7" casing.
The bent sub was not adjusted to achieve the required BUR.
Tripped out of borehole and adjusted the bent sub.
Review the BHA design and required BUR before the direction work. Consider the formation dipping while design.
R-603
FIT
Drilled 3m into new formation using 1.14sg mud. Circulated hole clean and performed FIT to 1.5sg EMW.
Performing the FIT with the original mud in hole then displace the well to new mud system saves time to circulate and condition the mud with the new system (at least two BU required), displacement to new mud system can be done while resuming drilling the 8 1/2" section.
FIT to be performed with original mud in hole and then displace to new mud system.
Drill 8 1/2" and drop to vertical
While drilling the drop section, attempted to slide for droping angle as per plan at 2500m MD in Rumaila Formation, difficulties to slide, string hanging and motor stalling, the tool face was very erratic. Also the pop off valve of mud pump had blown several times due to motor stalling. Attempted several times at different depths, drilling with rotary in between, continued to drill to Ahmadi formation and same issues while sliding. POOH to surface and RIH with new BHA (Blank sleeve on motor and 7 15/16" stab) and attempted to slide in Ahmadi, observed same issues. Decision made to drill rotary to top of Mauddud.
Recommendation to minimize sliding in Rumaila to avoid sliding across hard limestone strikes and Ahmadi across the top shale, BHA design has been reviewed for coming wells to include agitator to reduce downhole friction and stick-slip, improve the sliding performance.
RIH with optimized BHA, Implement to Drilling program and Sperry DoS
Perform wiper trip at TD
Performed short wiper trip for the new drilled section, worked tight spots and RIH to bottom found 7m fill, circulated hole clean, and increased MW from 1.26 sg to 1.27sg. No hole fill was encountered on condition trips
If more than 10% cavings are found on wiper trip, discuss with the office to increase the MW by steps of 0.01sg.
Monitor caving on wiper trip and discuss with office the forward plan.
R-603
R-603
138
NP_GX34_MI Drilling Program_WDI-840 performed after. R-604 20m3 dynamic losses recorded while displacement in 2nd stages most likely from Dammam formation.
LC-Materials could be added to lead slurry to help in plug losses zone and reduce the losses of cement to thief zone. LCM materials such as SteelSeal can be considered. WellLife 734 additive can be use as LC additive for cement.
Discuss with HAL CMT for best alternative products to prevent losses while cementing in current wells.
Well trajectory profile
Avoid to Build & Drop in the same section where possible, or plan to trip and change the BHA. R-604 well was trajectory designed to drop in 12 1/4" section due to trajectory and client requirements.
Agreed to stay with 1.5 bend on Motor. Suggest that DD's in future try variety of parameters. WOB to accommodate formation changes.
High torque spikes, added lubricant twice - 1st @ 1% (1556m) and 2nd @ 2% (1576m) concentration
Recognized that additives such as lubricant do help. Pointed out and agreed that small amounts are sufficient to avoid unnecessary waste, if the lubricant is not having effect, more % of lubricant will not improve effect. Continue using adequate sweeps or pills is a clear recommendations of Baroid. Continue using Barolift to avoid increasing in well ECD and shocking the hole.
Ensure is included and implemented in next Drilling Programs. Continue using adequate sweeps or pills.
Low ROP in 12 ¼” section
High vibration. Agreed possible high axial vibration
Evaluate implementation of new technologies to avoid vibrations. Evaluate use of Agitator to reduce hanging issues and improve ROP.
Evaluate use of Ag-itator to reduce hanging issues and improve ROP
Drilling 12 1/4" hole
During wiper trip performed Back ream from 1950 m to 2063 m with 1500 lpm, 50 rpm,1150 psi, (Attempted pump out several times, no success), decided increase mud weight gradually from 1.14 SG to 1.16 SG @ 2100 lpm, 1820 psi.SH-SH clean.
Use maximum mud density 1.14 sg in the 12 ¼” section.
To be included in the plan of next wells
Drilling 12 1/4" hole
Increasing the MWD flow rate settings to 2200- 2800lpm, has increased the power of the mud motor and helped to achieve better ROP while sliding and rotating
Increasing the MWD flow rate settings to 2200- 2800lpm, has increased the power of the mud motor and helped to achieve better ROP while sliding and rotating
To be included in the plan of next wells.
Cementing 9 5/8" casing
R-604 Low ROP in 12 ¼” section
R-604
Low ROP in 12 ¼” section
R-604
R-605
R-605
139
NP_GX34_MI Drilling Program_WDI-840 R-605
Cont. drilling 12 1/4" hole section with directional BHA in rotary mode at 1833m observed 5 m3 losses, pumped 3m3 LCM (40 ppb). No DHL.
Apply Stage tool selection decision tree for DV tool selection
To be included in the plan of next wells
Cementing 9 5/8" Casing
Losses in Hartha/Dammam
Add Injectrol Pre-flush in the 2 nd stage when exist losses down hole.
To be used in next wells
Drilling 12 1/4" hole
Increasing the MWD flow rate settings to 2200-2800lpm, has increased the power of the mud motor and helped to achieve better ROP wihile sliding and rotating
Keep using this setting range in the future wells
To be used in next wells
Wiper trip at top of Tayarat formation
Drilled to 1500m above top of Tayarat formation, performed wiper trip to KOP depth, recorded some tight spot but it was possible to pull out just lubricating and reciprocating the string, when RIH the hole was in good condition
the intermediate wiper trip helps to avoid long back reaming of the tight spot and contributes to keep the hole in good conditions
To be included in the plan of next wells
Increasing the mud weight to 1.14sg prior entering Tayarat
at 1500m, circulated and increased the mud density to 1.14sg prior entering tayarat, this is sufficient MW to control tayarat and also to help in stabilizing the hole above
in next wells, the mud weight to be increased to 1.14sg prior entering to tayarat
Carry on to next wells
RIH with 8 1/2" BHA
While RIH with 8 1/2" BHA with agitator on the string, attempted to full up string observed build up in pressure to 600 psi no return shut down the pump the pressers is stable @ 600 psi, repeat several time no success. POOH and checked each stand for any plug in string. Attempted to circulate with the Agitator and Shock Sub using two pipe screen one above and the other is below Agitator and resumed shallow test with FR 1700 lpm observed high pressure 1750 psi , disconnected and checked the drill pipe screen the lower had sufficient amount of gravels and sand the upper one was clean
Tool was filled with surface gravel. Inspection of tool prior to PU.
Check equipment prior PU & MU / flush in mousehole
Drilling 12 1/4" hole R-605
R-602
R-602
R-602
R-602
140
NP_GX34_MI Drilling Program_WDI-840 R-602
RIH with imaging tool
While performing wireline logging (RWCH-GR-DSNT SDLT-XRMI) with RA source in 8 ½’’ hole section, Recorded Main Section from 3555 to 3370m at 8 m/min. Tools held @ depth 3370, closed calipers and applied 50% of cable tension up to 12000 lbs, no success and jar not fired. Released the cable tension to zero and applied tension again to 12000 lbs, no success. Applied 60% of cable tension up to 14000 lbs, no success. (Tool stuck).RIH with fishing tool on 5” DP to 3330 above top of fish. Circulate above top of fish with, Cont. RIH and engage the fish @ 3350m with good indication. POOH 5" DP stands with wireline logging tools fish using reverse cut and thread procedure to surface
Tool got differentially stuck in a sand interval from 3362 to 3373m, the recorded differential pressure at this point was over 2500psi. Caution prior increasing the MW while dealing with caving across 8 1/2" section. ROO shared their experience in the field to treat the caving and MW is not the only driver for caving.
Assess the risks of differential sticking while drilling and logging the 8 1/2" section before increasing MW and increasing differential pressure.
RIH with 6" gauge ring
A 5.75' gauge ring was run instead of the standard 6" gauge ring. No obstruction found in hole and gauge ring pulled clean to surface.
As per Wireline recommendation, there is an increased risk of getting the 6" gauge ring stuck in deviated wells due to low clearance (7" 29ppf casing ID 6.18in).
Implement into drilling programs. If size of gauge ring is changed, communicate the change to all parties.
Survey
Discrepancies in TVD between Gyro and MWD surveys ~10m difference.
Investigation ongoing.
Logging
Partial caliper log for 8 ½” section, had to estimate average hole diameter based on offset wells for cement calculations. (increased excess to 30% to compensate for any extra volume needed)
Caliper is part of the logging program for 8 1/2" section.
Perform caliper log
17 1/2" BHA
17 1/2" BHA handling on rig floor, review BHA design with 8 1/4" DCs
17 1/2" BHA redesigned with 8 1/4" DCs for upcoming wells. Removed the 9 1/2" DC. Use this BHA configuration in next wells as it showed good performance and reduces 12 1/4" BHA. handling time.
Drilling Engineers aware and communicate the message to WSS. Implement in next wells and include in Drilling Program.
12 1/4" Directional
Observed dropping tendency while drilling Hartha
Design well trajectory and sliding plan considering high
Discuss with Sperry to include in the trajectory
R-602
R-602
R-602
R-606
R-606
141
NP_GX34_MI Drilling Program_WDI-840 BHA
formation. Inclination was about 5 deg below planned inclination.
dropping tendency in Hartha formation.
plans of upcoming wells.
Drilling parameters in Hartha formation
Drilling 12 1/4" hole section from top Hartha to final section with controlled drilling parameters.
Keep using controlled drilling parameters in this formation to avoid induce losses. Reduced drilling parameters 30m higher than top of Hartha and circulate hole clean at top
Drilling Engineers aware and communicate the message to WSS. Implement in next wells and include in Drilling Program.
9 5/8" Casing cement job
Optimize 9 5/8" casing cementing plan: recipe including Barolift fibers in Tail first stage in Lead slurry of 2nd stage. Add Latex 3000 in tail slurry 1st stage and lead slurry 2nd stage, use scavenger cement ahead of lead slurry in second stage and increase column of spacer to enhance the mud removal.
Continue using optimize 9 5/8" casing cementing plan. The optimization have contributed in good cementing job with good lift pressure and cement returns to surface.
Drilling Engineers aware and communicate the message to Cementing team. Implement in next wells and include in Cement Program.
9 5/8" Casing cement job
Ran caliper to have better volumes calculation and simulation.
Continue running caliper log.
Implement in next wells.
9 5/8" Casing cement job
Mud was conditioned with YP of 18 lbf/100ft2, circulated enough time for second stage ensuring that the mud is as per requested properties.
Continue keeping YP below 20 lbf/100ft2 (18lbf/100ft2 Optimal) and circulate for second stage ensuring that the mud is as required.
Evaluate the CBL-VDLCAST logs and incorporate the changes in the next jobs program.
Lubricant pills in 8 1/2" section
Performed additional sliding while drilling 8 ½” section. Possibility of big well tortuosity. Pumped and spotted 10m3 Lubricant Pill at 6.6 ppb to cover Mauddud and Ahmadi formation to provide Lubrication and reduce Drag during wiper trip. Pulled freely on elevator to 9 5/8" casing shoe. Run back to bottom, Found hole in good condition.
Continue pumping lubricant pills to reduce drag during wiper trips as necessary.
Drilling Engineers aware and communicate the message to WSS. Implement in next wells and include in Drilling Program.
8 1/2" Section
Observe Cavings while drilling 8 1/2" section, increased MW from 1.24 sg to 1.26 sg. No more Cavings observed.
Optimize Mud weight whenever cavings are observed, depending on cavings type, failure and quantity.
Implement in next wells.
17 1/2" BHA
Used BHA with 17 1/2" Bit, Bit sub, Shock sub, 9 1/2" NMDC, 17 3/8" IBS, XO, 6 x 8"DC, Jar, 2 x
Use this BHA configuration in next wells as it showed good performance and reduces the handling time for BHA in 12
Include it in future well's drilling program
R-606
R-606
R-606
R-606
R-606
R-606
R-607
142
NP_GX34_MI Drilling Program_WDI-840 8 1/4" DC, XO, 27 x 5" HWDP and removed the 9 1/2" DC as in prvious programs. To R-607
1/4" BHA
Cementing 13 3/8" Casing
70% tail + 150% lead
Cut 20" conductor
After cutting the 20" conductor, observed water flow from 20" x 13 3/8" annulus, closed the conductor drain valve in the cellar, water level stabilized.
This flow is due to shallow water table. Special consideration to be taken while drilling close to river or during summer time.
Civil contractor to inform about any flow while working on cellar or conductor pipe.
Cementing 9 5/8" Casing
Changes in cementing program: recipe including Barolift fibers in Tail first stage in Lead slurry of 2nd stage. Add Latex 3000 in tail slurry 1st stage and lead slurry 2nd stage, use scavenger cement ahead of lead slurry in second stage and increase colume of spacer to enhance the mud removal.
In addition to the changes in the slurries and spacers. We have run caliper to have better volume calculation and simulation. Ensured that the mud is conditioned with YP of 19lbf/100ft2, circulate enough time for the second stage ensuring that the mud is as per requested properties. Increasing the flow rate for displacement. all those measures have contributed in having good cementing job with good lift pressure and cement returns to surface
Evaluate the CBL-VDLCAST logs and incorporate the changes in the next jobs program
Drilling 8 1/2" hole section
in 8 1/2" hole section, sliding has been performed in Saadi formation to drop angle as per plan, the trajectory was below plan which reduced the sliding time, then drilled ahead the remaining interval down to TD in rotary mode as the BHA was dropping which enabled hitting the target within target tolerance (50radius)
follow up the BHA tendency, in case of dropping keep rotating and reduce sliding time
Practice to be followed in next wells
Cementing 13 3/8" casing
Redistribution of cement excess to 70% on tail and 170% on lead.
This redistribution reduced the ECD and showed improvement in cementing 13 3/8” casing. Observed 26m3 neat cement returns and no losses during cementing operation.
Implement to next cement programs
Drilling 12 1/4" Section
No sliding was performed to drop angle and keep the well below the plan. Had to perform sliding in Hartha formation to drop angle to 5.84deg which put section TD
If difficulties are encountered while sliding, DD to communicate with office prior continuing on rotary. Send projection with expected tendencies after each survey to
Instruct DD to send projection after each survey. DD to make required slides are performed to not miss
R-607
R-607
R-607
R-608
R-608
143
NP_GX34_MI Drilling Program_WDI-840 at 16.75m above plan and 1.41 left to plan.
office.
target.
Cementing 9 5/8" Casing
% excess, Latex-3000 in Tail slurry, VersaSet in lead slurries and Barolift LCM Material shows positive results to improve cementing job and ZI.
Keep current design.
Implement to next cement programs
8 1/2" Hole section Wiper trip
Difficulties to RIH Wireline logs to desired depth.
Conditional wiper trips should be complete to the Casing Shoe after reach well TD.
Implement in next drilling programs
8 1/2" Hole Section
Circulated and reciprocated string in the same point due to mud pump failure.
If pump repaired is more than 1hr, POOH to shoe, make wiper trip, circulated at minimum flow rate.
Implement in next drilling programs
8 1/2" Hole Section
Control ROP on shales, formations with stability issues.
Design ROP strategy per formation or intervals to control ROP in required formations.
Implement in next drilling programs
8 1/2" Hole Section
Difficulties to RIH Wireline tools and log desired depths.
Optimize wireline logs assemblies strategy (decentralizers, nose, arms) tailored to tool type to assist running WL tools and log desired depths.
Implement in next drilling programs
17 1/2" BHA
Used BHA with 17 1/2" Bit, Bit sub,Shock sub, 9 1/2" NMDC, 17 3/8" IBS, XO, 6 x 8"DC, Jar, 2 x 8 1/4" DC, XO, 27 x 5" HWDP and removed the 9 1/2" DC as in prvious programs.
Use this BHA configuration in next wells as it showed good performance and reduces the handling time for BHA in 12 1/4" BHA
Include it in future wells drilling program
Cementing 13 3/8" Casing
Used Cement excess of 70% tail and 170% lead reduced ECD and improve 13 3/8” casing cement (8m3 cement returns, no losses)
Maintain the same design and procedure which was used for the current job and all the previous jobs due good results
To be followed in next wells
Cementing 9 5/8" Casing
Used Cement excess 20% in open hole, 40% 2nd stage, 30% 2nd and 30% 2nd lead, included Latex-3000 in the Tail slurries of 1 st & 2nd stages slurries, VersaSet Additive in the lead slurries of 1 st & 2nd and Barolift LCM Material were utilized for 1st stage Tail and 2nd stage Lead slurries
Maintain the same design and procedure which was used for the current job and all the previous jobs due good results
To be followed in next wells
R-608
R-608
R-608
R-608
R-608
R-609
R-609
R-609
144
NP_GX34_MI Drilling Program_WDI-840 R-609
8 1/2" Hole section Wiper trip
"RIH wireline tools Run#1(TET-SP-ICT-IDT-DLL
R-609
-MSFL) at 2409 m stop attempted to pass many times with different speeds, no success, POOH removed ICTIDT and RIH again Run#1(TETSP-DLL-MSFL) stop at 2396m, try to change speed tools didn't pass"
Complete Wiper trip Condition to Casing Shoe after to reach TD well.
R-609
8 1/2" Hole section Wiper trip
Performed POOH with pumping out and high flow rate (similar as in the driiling)
When pumping out use minimum flow rate.
Practice to be followed in next wells
R-609
8 1/2" Hole Section
During the repetitive failures in Mud pumps, circulated and reciprocated string in the same point.
If pump repaired is mayor than 1 hrs, perform a wiper trip, if not circulated at minimum flow rate.
Practice to be followed in next wells
R-534
The logs showed poor quality cement job for 9⅝” casing
Used CBL-VDL to log the light weight cement
Used the right log to recorded the light weight cement.
Use URS tool to log the light weight cement.
Zonal Isolation not achieved in Nahr.Umr formation
Enlarged borehole in 8½ section due to washout, resulted in cement channeling and inadequate cement coverage.
No remedial cement job has been carried out.
Improve the drilling practices and mud properties to deliver better borehole stability.
stage collar malfunction
Several attempts to open stage collar with pressure and mechanical force, no success.
Stage Collar Tool supplier engineer to be at rig site for all next jobs to inspect and run 9⅝ stage collar and MSIPC.
R-552
R-552 9⅝ stage collar did not open for second stage cement job.
Practice to be followed in next wells
Consider using stage collar packers.
Carried out remedial cement job through perforations and achieved zonal isolation.
Cover and clean the stage collar by pumping water for the first 60 bbl 145
NP_GX34_MI Drilling Program_WDI-840 of first stage displacement. Slow down the displacement rate (2bpm) prior the shut off plug reaches the stage collar collar. R-552
Got stuck while drilling 8½” borehole at
Due to differential sticking
Pumped 5.5 m3 pipe Lax, got string free.
2726m, after connection
R-554
Work on the string by 50 ton jarring down.
Human error
Recovered the bit by Magnet.
8½” bit dropped in the wellhead
R-554
Ensure that the pipe is free (no overpull) prior to make connection. Minimize the stationary time of string in open borehole without pipe movement. Ensure that the bit breaker is closed properly. The blind ram should be closed when there is no pipe in the borehole.
The borehole instability
Borehole Pack off while displacement 7” casing cementing
Tried to displace with high pressure up to 4900 psi, no success. DOC inside the 7” casing and carried out remedial cement job.
Keep circulation before the cement job until borehole clean and get pressure stabilized. Make sure that the mud weight is matching with the drilling program. Reciprocate the casing while circulation and condition the mud.
R-554
Slick line tool failure POOH w/ 3 ½” completion prior setting 7” PKR
R-557
R-557
POOH w/ completion and changed the setting mechanism from using W/L plugs and used hydro trip sub.
Make sure that the shear pins of the W/L plug is competent enough for setting. Use hydro trip sub for PKR setting as an alternative option.
Drilled Dammam formation without losses.
Drilled Dammam with controlled ROP and low flow rate (500 gpm and ROP 5 to 8 m/hr)
Changed 8½” borehole directional BHA design
To avoid drill string stuck after 40° due to accumulation of cutting in the low side
Control the ROP while drilling Dammam FM. Reduce the flow rate to reduce the ECD. L/D DC’s and replaced by 5” HWDP.
Avalanche effect should be considered while design directional BHA. 146
NP_GX34_MI Drilling Program_WDI-840 (removed the DC) after reach 40° inclination
(avalanche effect)
RIH and POOH smoothly without overpull while drilling 8½” borehole
The mud properties were matched with the drilling program.
R-549
Got difficulties to install the cement head for 13⅜” casing
Improper casing stick up
L/D the last joint and replaced with casing pup joint to have 1.5m stick up.
Adjust the casing tally to have 1.5 m casing stick to facilitate installing the cement head.
R-549
Observed leakage from cement head while circulation before the 13⅜” casing cement job
Seal damaged
Replaced the Seal immediately.
Check and ensure that the all equipment is integral prior the job.
R-549
Obstruction while POOH with wiper trip after reach the TD
Wiper trip while drilling was not performed as per program
Back reaming the tight spots until get smooth borehole.
Perform wiper trip every 500m.
R-557
R-546 While test 13 ⅝”-10K psi BOP, got pressure drop from 3800 psi to zero. Opened the 5” pipe ram and tried to retrieve 13 ⅝” Nom test plug, no success
Use fresh water while prepare the new mud (do not use water from the waste pit).
The DLS is not aggressive to make borehole geometry problem.
Keep the DLS within the optimum range.
The wiper trip should be covered the entire open borehole section. The test plug stuck inside CHH while test the BOP
Tried to retrieve with 75 Klb overpull, no success.
Check the test plug type and size before using it.
Ran 6 ½” fishing assy.: (6 ½” fishing Jar + X/O + 2 X 6 ½” DC) worked on the plug by jarring up to 100 Klb, got released. Ran with storm valve plus 13⅜” DLT packer and set same at 28m in 13⅜” casing, tested to 900 psi, Ok. N/D BOP & checked CHH internal profile, OK. N/U BOP, pressure tests BOP APP, retrieved storm valve and 13⅜” DLT Packer.
R-611
Cementing 13 3/8" Casing
Dumping large amount of lead cement returned to surface in last wells, in R-611 dumped 8.3m3 of lead
Optimize the volume of lead cement pumped during 13 3/8" cementing job. Reduce the cement excess from 170%
Include it in next drilling program
147
NP_GX34_MI Drilling Program_WDI-840 cement.
to 150%.
R-611
Drilling 12 1/4"
Using 8" Agitator system has enhanced the performance of directional BHA, following the planned trajectory to build up and drop angle in the same section, the BHA was able to drop without issue with smooth tool face, in previous well R-604, the BHA without agitator could not drop and had to POOH and remove sleeve stabilizer
Use Agitator in 12 1/4" BHA in case of well trajectory similar to R-611 with build and drop angle in the 12 1/4" hole section
To be used in next wells if applicable
R-611
POOH 12 1/4" BHA with Backreaming
While POOH with 12 1/4" BHA from 1701m to surface, faced tight hole and had to POOH with Backreaming in Shiranish, Tayarat and Um Er Radhuma. Hard backreaming has been reported up to the point where 8" Agitator system was reaching vertical Hole, it though that 8" AGT is causing bottleneck in middle of 5" HWDP, causing drag.
Use 6 3/4" Agitator in 12 1/4" instead of 8", this will cause less change in body size and smoother transition
To be used in next wells if applicable
R-611
POOH 12 1/4" BHA with Backreaming
After reaching TD, POOH for wiper trip experienced several intervals with backreaming in Hartha Shiranish Tayarat and UER. It has been recorded same backreaming and tight spot in offset wells, backreaming was specially experienced in drop and build up section. In the last trip out of hole, spotted 55m3 of StickLess pill to cover build up and drop section, then pulled freely to surface
Spot StickLess Pill in build up and drop section to lubricate the trip
To be used in next wells if applicable
R-611
Partial Losses in Dammam while drilling and pulling out
While drilling 12 1/4" hole and tripping, recorded discontinuous 3-1.5m3/hr dynamic losses and static 0.5m3/hr in Dammam, swept the hole with 40ppb LCM pills which has contributed to reduce the losses to
In case of partial losses in Dammam, spot 140ppb LCM pill across Dammam
To be used in next wells if applicable
148
NP_GX34_MI Drilling Program_WDI-840 1.5m3/hr dynamic. On the final trop prior casing Spotted 17m3 140ppb LCM pill through PBL sub, the well was static with no losses. RIH 9 5/8" with no downhole casing R-611
Drilling 8 1/2"
Controlled ROP (20-25 m/hr) during drilling all section
Observed hole in good condition, no issues during wiper trip and running logs
Include it in next drilling program
R-612
Drop 12 1/4" Rotary BHA off at Drilling Program
Saving Time in 12 1/4" hole section.
Considered 12 1/4" directional BHA to drill all section, using SentinelCem in case of losses in dammam formation.
To be included in the next dirlling program
During drilling 12 1 /4" hole section from depth 819 m to 860 m, at 819 m observed 15m3/hr DH losses, performed 1 st SentinelCem PLUG, unsuccessfully
Consider to perform 2 SentinelCem Plug when exist two losses zone.
To be included in the next dirlling program section: Dammam Lost circulation strategy
Use 2 leads slurries to Enhance CBL results
Use Two Leads slurries on 9 5/8’’ Casing job both slurries with 1.45 s.g density. First lead was designed to be placed in between csg/csg the design doesn`t have any Cenospheres products, Microlite-P (compressive strength enhancer) was used in the slurry to provide a compressive strength of 1,000 psi -The second lead was pumped to be placed in between the O.H and Csg, CBL results were showing an improvement in the csg/csg section
To be used next jobs.
Use 2 pup joints in the 7” csg To be served as markers for reservois to improve correlations
one to be located in USM and the second one top Mishrif
To be included in the next wells
Avoid damaging WLEG while RIH 3 1/2” Tubing on 3 1/2” DP
- Ensure the distribution of 3 ½” DP tally to all parties Prior starting RIH -RIH to 1 meter above cement / Float Collar (if any cement observed with gauge ring)
To be implemented in the next wells
R-612 Cure losses in Dammam formation
R-612
for 9 5/8”cementing
R-612 RIH 7” casing
R-612 RIH 3 ½” Tubing
149
NP_GX34_MI Drilling Program_WDI-840 Don’t apply any weight on WLEG. - DSV is present on the drill floor at the determined critical wash down point R-612
Wrong tubing head adaptor was mobilized on location
It was thought that the Dummy Penetrator hole was not fitting on the tubing spool.
it is required that Cameron Engineer has to perform full equipment check before call out and once on location
During cementing operation, returned to surface 33.8 m3 (213 bbl) of pure cement 1.45 sg.
Maintain the excess for tail slurry, and decrease the excess of lead slurry volume.
Apply to the next well
Introduced new bit design MMD65DMH matrix body with 6 blades and 16mm cutters, however observed low performance During all conditioned wiper trip observed hole in good condition
Use the old bit design SF66 in order to continue improving performance wells as were observed last wells
Update drilling program with the SF66 bit design
Optimized mud properties and inhibition based on formation properties combined with controlled parameter lead to achieving good hole quality. Continue with optimized Mud program for Mishrif vertical well.
Same formulation to be used in coming wells
Maintain the excess for tail slurry, and decrease the excess of lead slurry volume.
Apply to the next well
NU the THA
R-613 13 5/8" Casing
R-613
Drill 12 1/4" hole
R-613
Wiper trip 8 1/2" hole section
R-613
Drill 8 1/2" hole
R-615
Cementing 13 5/8” Casing
R-615
Drill 12 1/4" hole
During drilling 12 ¼” hole section achieved ROP 16.8 m/hr
Optimized surface parameters (WOB-RPM FR)
Update drilling program with same parameters.
R-615
Wiper trip 8 1/2" hole section
During all conditioned wiper trip observed hole in good condition
Optimized mud properties and inhibition based on formation properties combined with optimized surface parameters lead to achieving good hole quality.
Same formulation and surface parameters to be used in coming wells
R-615
Drill 8 hole
The caliper logs showed very good 8 1/2" holes with 8.76"
Continue with optimized Mud program for Mishrif vertical
Same formulation to be used in coming wells
1/2"
The caliper logs showed very good 8 1/2" holes with 8.53" (1.00% Washouts) average hole diameter. During cementing operation (Used 150% excess, 20% less than last well), However returned to surface 38 m3 (239 bbl) of cement 1.5 sg.
Same formulation to be used in coming wells
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NP_GX34_MI Drilling Program_WDI-840 (1.03% Washouts) hole diameter.
average
R-617
Cementing 13 3/8" Casing
Dumping large amount of lead cement returned to surface 20 m3 cement returns.
R-617
12 1/4” Conditioned wiper trip.
Hard backreaming while performing Wiper trip from top of hartha formation to 13 3/8” casing shoe
R-617
8 1/2" Hole section Wiper trip RIH 7” casing
Difficulties while RIH CAL-GR log. At 2469m tools held up, attempt to pass, no success Use 2 pup joints in the 7” csg To be served as markers for reservois to improve correlations While running with 9 5/8” casing, observed 20 – 24m3/hr losses starting from 1800m. Continued to RIH to bottom and spotted 40ppb LCM pill and waited to soak, dynamic losses reduced to 5m3/hr. Cemented the first stage of 9 5/8” casing with good signs that the cement was brought to the desired top on the first stage, modified the plan to include LCM pill ahead of the spacer, added 7ppb and 8ppb of SteelSeal to spacer and tail cement respectively. After opening the DV circulated 22m3 of spacer out and 8m3 of contaminated cement. Cured losses in Dammam prior to pump second stage cement and observed 22m3 of lead cement at surface. Recipe was modified to include 100% excess on lead #1
R-617
R-618
RIH with 9 5/8" casing
R-618 Drill 12 1/4" hole
MM65DMH was first introduce in Ru-469 to drill 12 1/4" hole vertically to section TD. Good performance was delivered by the bit. On R-618, the bit was tried for the first time on a deviated well, the bit showed
well.
Optimize the volume of lead cement pumped during 13 3/8" cementing job. Reduce the cement excess from 170% to 160%. Try to smooth the directional trajectory design in order to minimize tortuosity generated by high dog leg. Specifically long step out well. Complete Wiper trip Condition to Casing Shoe after to reach TD well one to be located in USM and the second one top Mishrif
Include it in next drilling program
To be included in the next wells
Practice to be followed in next wells To be included in the next wells
Over confidence that no losses would be observed since no losses were observed while drilling 12 1/4" hole with maximum parameter hence no LCM pill was spotted across Hartha and Dammam formation.
Precautionary spot LCM pill across thief zones to help reducing losses while running in hole with casing. LCM to be washed out of hole while running casing.
The MM65DMH runs would be limited to vertical wells
HDBS to adjust their inventory as per the drilling schedule to run this type of bits or stick to the current design which showed good performance in both 151
NP_GX34_MI Drilling Program_WDI-840 low performance starting from ~1500m inside Tayarat formation.
types of wells.
18.14.2 South Rumaila Wells Well
Description
Reason
Action Taken
Recommendation
Pick up 17 ½’’ BHA
P/U and M/U 17 ½’’ BHA with no supervision from the rig tool pusher. There was a lot of confusion among the floor hands & driller
Toolpusher needs to be at rig floor for any BHA make up especially if the rig crew still has no enough experience with rig tools.
Toolpusher & DSV to be at rig floor while making up the Bit & the BHA for any section.
Making up 17 ½’’ BHA
Each DC size should have a safety clamp ready for use.
Ru -441
There was only one safety clamp at rig floor to be used for 9 ½’’ DC then modified to 8 ¼’’ DC resulting in wasted time
Good preparation & planning for BHA picking/making up. All the tools are available to deal with deferent tubular.
Ru -441
Drilling 17 ½’’ BHA
Consider the shock sub for 17 ½’’ BHA to minimize bit jumping
Ask Sperry to design the 17 ½’’ BHA with shock sub
Ru -441
RIH 13 3/8’’ by over drive system
No shock sub in the BHA, excessive bit jumping especially when start drilling with few DCs RIH casing without wiper trip as the hole was in good condition while POOH
With a good hole condition and by using over drive system we can eliminate the wiper trip
Consider the ODS for next well
Ru -441
RIH 13 3/8’’ by over drive system
Need to break out the TDS saver sub to fit the ODS connection 6 5/8’’ Reg
Time wasted due to poor planning
Prepare a cross over from the saver sup to the ODS.
M/U 12 ¼’’ BHA
With no supervision from the rig toolpusher.no organization tools on the rig floor.
Toolpusher or N/Toolpusher needs to be at rig floor for any BHA make up. Paper and organize proper tools for job on rig floor e.g. Slips, chain, safety clamp,..etc.
Toolpusher & DSV to be at rig floor while making up the Bit & the BHA for any section.
One Plastic liner water pit to saved water from the water well not enough to cure losses in Dammam FM when implement blind drilling,
Considering to saved water from water well in two Plastic liner water pits, also need two tanks in the mud system to use it as storage for water well, 1500 m3 minimum amount of water well we need to store it before entering Dammam FM.
CPM management should arrange this serious issue to cover two Plastic liner water pits before start spud to minimize the time and the coast of the drilling.
No drill blind more than 40 m, the total mud volume is not enough to drill blind
Keep the suction full of light drilling fluid and top up with water as required.
Once the drilling fluid supply is depleted, continue pumping water
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Second water pit
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Mud plan to cure losses
Check and organize all tools which is need to do
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NP_GX34_MI Drilling Program_WDI-840 more than length.
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Cement plug plan
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Thixotropic cement plug
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Cement plug with high compressive strength
Drilling through Dammam fm with no cement plug plan in place. There was a lot of confusion for the proper cement plug to be used Pumped 2 thixotropic cement plugs as losses control. The second one was no completed successfully
2nd Thixotropic lost circulation plug pumped did not cure losses because slurry did not develop thixotropic properties when on static conditions. Once mixing cement slurry, it was noticed that the slurry was too thin. It appears that the causal factor was cement blend which was contaminated during transfer from one bulk truck to another.
LCP # 4. Pumped 5m3 of cement to cure losses. Spent 9.5 hours drill out cement plug (+- 70 m length)
The values of compressive strength were high (500 psi in 5 hrs). Risk of side track while drill out
Drill out cement plug in Dammam FM with water
Ru -441
Drill cement plug with water in Dammam FM
Need to prepare a good plan early before drilling through Dammam
Collateral damage for the drilling out cement with water. 1- Remove filter cake from the wall hole. (Seen on shakers). And partial losses happen in the upper section of Dammam which already don’t have losses in the last. 2- Can’t recognize the cement percentage in shakers samples, because washed the upper section of Dammam. (Side track risk).
down hole, keep 40 m3 of drilling fluid in the reserve tanks for use with hi-vis pills. Getting the cement plug plan as early as possible. This plan to include complete & partial losses events & to be up to 4 plugs. 1. Ensure bulk equipments are clean for cement transfer and storage on location: Cleaning Bulk trailers/Storage tanks will consist of blowing them a minimum 3 times to any available designated waste containment area. Visually check the cleanliness of the inside of each Bulk trailer/Storage tanks on a regular basis (at least every 30 days) and document record of visual Pressure vessel on Inspection form. Design cement plugs to cure losses with low compressive strength values. Drill out cement plug with normal mud to illuminate filter cake erosion.
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NP_GX34_MI Drilling Program_WDI-840
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RIH mud motor with BH at 0.75 deg
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Directional tools setup
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Drilling 12 ¼’’ hole with controlled MW
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Ru -441
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Run 9 5/8”
Landing 9 5/8” CASING
Cementing job
RIH 12 ¼’’ BHA with 0.75 deg bent sub
Poor sliding outcome , the V.S distance was 15m center to center
RIH 12 ¼’’ BHA with 1.5 deg bent sub for better sliding & quick outcome.
- Need good communication between Sperry DD/MWD & DSV - Consider the minimum & maximum flow rate. There was no mud - Need good solid control centrifuge on rig site equipment. WDI must resulted in poor control for ensure this. the MW and - Need Mud centrifuge. dump/dilution many times Baroid should supply this.
MWD tool limit to be set early before RIH by communicating the DSV
Late setup for the directional tools (MWD)
9 5/8” mandrill hanger couldn’t pass the FMS SLIP of TRS (the neck is 13 5/8” OD)
We spent half hour figure out how to land the casing and reset the FMS in rotary finally decide to use the casing slips
We made up the landing jt to the running tool during the first job
Since we have it complete torqued up and fit to our rug
Spent more time in the 1 stage job due to wait on cement based on UCA results (minimum 500 Psi compressive strength) was higher (+-7 hrs more)
The 1 stage slurry was design with 71 °C according drilling program information. Final temperature according caliper log once ran was 55 °C; therefore, the time WOC to pump 2 stage based on UCA was higher
9 5/8”
Cementing team had not enough time to blend slurry again and send to rig
Ru -441
Ru -441
Drilling 8 ½” hole
Drilling 8 ½” hole
Drill with inconsistent parameter, differential pressure and WOB
Drilling with consistent parameter will improve performance
Slide drilling in Nahr Umr for 15m
No sliding in shale, Tanuma or Nahr Umr or any shale, and decrease the interval of sliding like slide for 5m and rotary for 5m to give chance for cleaning
- WDI to perform a serious maintenance on the S.C.E - Baroid to send the mud centrifuge to the rig site ASAP - Directly after finish run the casing release the FMS and use 9 5/8” casing slips safety clamp both are 250 ton - It’s better keep it in our location for our rig, always should be cleaned and maintained for the next job - Wait for final temperature value from e-log to complete blend the slurry - Consider use MultiStage Inflatable Collar Packer to decrease the WOC time before 2 stage cement job - Driller to keep watching and maintain programmed parameter, auto drill function to be activated if possible - Maintain the well trajectory from the 12 ¼” and do sliding not in any shale formation. - No slide in shale formation and 154
NP_GX34_MI Drilling Program_WDI-840
-No dead volume into active tank-suck from the bottom (settling).
Ru -441
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8 ½’’ directional tools and 8 ½’’ bit plug w/cutting
8 ½’’ directional tools and 8 ½’’ bit plug w/cutting
Extra time circulation and space out with 7"casing at
-Cuttings were found in suction tanks - only one equalized line in the third intermediate tank. -didn’t use DP screen in the filling and break circulation.
-Make dead volume at least 1 foot (Suck from above of the dead volume) -Make equalized line in the first intermediate tank and transfer window in the mid of others intermediate tanks. -Use DP screen at any short circulation time even fill string.
-
-
permeable zones as Mishrif and Rumalia Need plan to modify mud system Dump settling tank contentiously during drilling operations. Check and clean intermediate and suction tanks during drilling operations. Use drill pipe screen always even for short circulation time.
- No dead volume into active tank-suck from the bottom (settling). - Cuttings were found in suction tanks - only one equalized line in the third intermediate tank. - Did not use DP screen in the filling and break circulation.
- Make dead volume at least 1 foot (Suck from above of the dead volume) - Make equalized line in the first intermediate tank and transfer window in the mid of others intermediate tanks. - Use DP screen at any short circulation time even fill string.
- Need plan to modify mud system - Dump settling tank contentiously during drilling operations. - Check and clean intermediate and suction tanks during drilling operations. - Use drill pipe screen always even for short circulation time.
Spent extra time trying to reach the bottom in conditions of high drag high circulation pressure, could not reach the bottom after trying to wash out, circulated extra time in order o clean the hole and having stable pressure profile
- Plan for probability of not being able to tag bottom due to presence of fill at bottom - Discuss with client the possibility to drill few meters deeper in order to have margin, in case of not being able to reach the bottom, L/D one joint and space out correctly face to zone of interest (Having HUD lower than expected perforation interval) Have a set of pup joints on site which permits to be flexible and space out correctly according to new shoes point, since we are using compact well head
- Verify the tally and having in mind the possibility of laying down one joint. - Request set of pupjoints during the preparation of the job
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NP_GX34_MI Drilling Program_WDI-840
Ru-441
Ru018A
Ru018A
Circulation with fill up tool (high pressure)
Spud the new well Ru-047A
Make up 17 ½” PDC bit
- The fill up tool did not allow to circulate with surface pressure more than 1500psi
Was planned to use the water well to mix the spud mud, when the water well pumps installed the water tested and it show high salinity and hardness; unusable to mix the spud mud Test results: cl- = 6000 m/l * ca++ = 960 mg/l * total hardness = 1560 mg/l
Not able to M/U PDC bit, the bit breaker not fitting to rotary table
- Check the specifications of the fill up tool prior to send to the rig
Prepare mud with fresh water
PDC bit breaker not fitting into rotary table. Could not M/U planned PDC bit and ran with re-run Tricone bit.
- prior to send the fill up tool to the rig, discuss with provider and make sure that the pressure rating permit to circulate with circulation pressure expected at bottom Check the salinity of water well in advance and prepare the mud system to collect fresh water, make sure no leakage to not waste the water
Ensure that the correct bit breaker which fits to the rotary table is available at the rig site before spud the well
Most of next wells are planned to run PDC in this section
Ru018A
Ru018A
BHA design
Running 13 3/8 casing
Ru018A
BOP N/U and test
Ru-
BOP pressure
Include shock sub in 17 1/2" BHA
Made up 13 3/8” rigid centralizer, that rigid type did not pass through slips of the over drive system, was necessary release it and replace with type bow. Tester plug could not pass through drilling spacer on BOP
BOP stump tested during
Change the BHA per program and add shock sub in 17 1/2" BHA with Tricone bit to minimize the axial vibration in surface and enhance the ROP 13 3/8” rigid centralizer cannot be run through the FMS slip
While RIH, the test plug assembly, could not pass thru 13 5/8" drilling spacer, decision made to replace it. N/D BOP, the spacer removed found there is a welding inside the flange decreasing the bore hole of the flange so the plug not pass (unsatisfactory performance), change the spacer. The BOP as tested off line on
Include the shock sub in the future 17 1/2" BHAs that are planned to use Tricone bits Ensure in every 13 3/8” casing run use centralizer type bow.
Check all bop components and make sure the test plug can pass all components without restriction
Mention in the drilling 156
NP_GX34_MI Drilling Program_WDI-840 018A
Ru018A
test prior to drill 12 ¼” hole
rig acceptance and we fully test it again as per programme.
stump and documented, after N/U the BOP on top of CHH the BOP was fully tested again on line losing the time of double test
BHA with string stabilizer close to the bit resulted in 3.81deg. Inclination
The BHA has been changed from the last well by removing the near bit stabilizer and having just string stabilizer.
17 1/2" BHA design
Slow ROP while sliding with 12 1/4" Directional BHA Ru018A
Add a 9 ½” DC below stabilizer to get more pendulum effect (string stabilized at 20m)
Used 2 thixotropic plug to cure losses of 1.44 sg of 140 bbl in place and second one of 80 bbl Thickening time of 4 h: 30 min; the total operation time take 40 min to put the 140 bbl plug in place, safe margin 3 h: 50 min
Curing the losses in Dammam with LCP
Drilling 12 1/4" with directional BHA
-
However in the new BHA the stabilizer was not enough far from the bit by having only bit sub float sub and shock sub between the bit and string stabilizer (6.44m, 22 ft.), the result was 3.81deg. inclination measured by EMS tool at the end of the section Cured losses in Dammam with 2 cements plugs
Ru018A
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program that if the BOP was tasted on stump, no need to test it again after N/U, just need to perform shell test on the connection with wellhead Re design the BHA in future well to maintain verticality.
Sliding was complicated by bit aggressiveness, string Hanging and erratic TF. Sliding was performed with minimum differential pressure to control TF. Sliding in Shiranish was relatively easier due to less hanging in limestone formation and more controllable
Good results to cure losses with thixotropic slurry plugs of 1.44 SG. Reduce the thickening time from 4 h: 30 min to 3 hours. - With low thickening time the cement slurry will set faster and will not go deeper into the formation. Reduce also the longer WOC - Possibility to cure Dammam seal Dammam with one plug. Re-design the BHA. - Change the bent housing of motor to 1.22 deg as maximum - OD motor sleeve and stabilizer under gauge (less than 12”) - Setting MWD for higher flow rate to permit more flow - Include more 8 ½” DC below jar to has 157
NP_GX34_MI Drilling Program_WDI-840 enough weight to drill
Hard back ream and very slowly with high torque and over pull. Spent 3.51 days
Ru018A
The WOB was limited due to high torque on bit Drill 12 ¼” section directionality avoiding high doglegs and high turn rates values Near bit and stabilizer size should be under gauge (less than 12’)
Wiper trip after drill 12 ¼’’ hole to section TD
-
Ensure to ream every stand drilled till torque and over pull values be low and any drag show.
Change motor bent housing to 1.22 deg as maximum to avoid tortuosity in well profile Perform a short trip at top of Hartha. Next deviated wells’ S shape or J Shape we will us 3% of lubricant from the beginning of section and keep this concentration till end section.
Maximum dogleg 3º/30m. Perform FIT at 1769m TVD with mud of 1.14 sg to get EMW of 1.5 sg
Ru018A
Drill with high torque up to 20 klbs-ft
Ru018A
-
Start to pump 0.25 bpm to increase the pressure up to 900 psi without realizing the formation value of leak off was less than 900 psi; the formation broke at +-666 psi – EMW 1.4 sg.
FIT below 9 5/8” shoe
Drilling 8 1/2" with directional BHA
The FIT was planned to get an EWM of 1.5 sg with 900 psi.
The 8 ½” caliper log showed washout below 9 5/8” shoe of 18 inches (+- 7m of washout) Used 3 different BHA to drill whole section due to high torque First BHA with slick 7” motor, adjust bent housing at 1.22 deg and 8 ½” stabilizer Second BHA: eliminate motor and run conventional BHA and 8 ½” stabilizer Third BHA: include motor with bent housing 0.0 deg, 7 5/8” stabilizer and add HWDP below jar to drill with
Follow the procedures to perform FIT according is recorder in the drilling program While a FIT is performing, be alert to any change and drop in the pressure as indicator of leak
Re design the 8 ½” BHA in directional wells, run slick motor and 1.22 bent housing as maximum Eliminate the 6 ¾” DC in the BHA and replace by 5” HWDP to reduce the torque in the string according T&D simulation Add more weight below the jar to drill with it in tension
158
NP_GX34_MI Drilling Program_WDI-840 the jar in tension
Ru018A
Ru018A
Ru018A
Wiper trip prior to run 7” casing
Use 7” centralizer stop ring bolt type
Spot a Hi-vis pill on bottom to cover Zubair formation prior to run 7” casing
Due to high rheology of that pill is not recommended spot on bottom due to increase the pressure while is circulating prior to cement job
Not spot a high vis pill prior run 7” casing, in case to pump, circulate hole to has return of pill in surface
The types of stop collars received in the rig were different (OD bigger) to conventional stop collars using with rigid and bow centralizers. Were replaced by conventional type Use this tripper hydraulic instead of use rig cat walk.
The stop collars bolt type may cause casing stuck and not able to run it to bottom (only 1/8’’ clearance between the stop ring and the open hole).
Stop collar supplier always must to be providing screw type or spiral nail type of stop ring.
Easy to rig up, easy handling for TRS & rig crew. Less man power required for lay down or pick up dp, casing and utilized same man power on other task Minimize using of lifting gears & tugger. Overall all on the top safety factor view, this is good machine to prevent hands & fingers, manual handling, body posture Prior to displacement the cement, the line to the rig from cement unit was not flush; its means was pumped +- 2bbl of dead cement volume (+- 17m of high inside casing)
Keep this machine to use in the next casing jobs & pick up & lay down drill string. also need back up for this machine.
Use Weatherford TRS tripper hydraulic catwalk for lift 7’’ casing & drill string.
Run junk basket and tag bottom at 3344m (19m above float collar).
Ru018A
Cementing job in 7” casing
Ru-443
Drilling 17 ½” Hole
Ru-443
Pressure Test
Torque tube loose while drilling due to TDS vibration and lock clamps from Aframe and from Centre are missing.
After testing 13-5/8" BOP, while POOH test plug to
Follow pumped 10 bbl of water from cement unit before to continue the displacement with the rig pumps WDI should provide proper supports as per OEM recommendations to make it a stable structure.
- To ensure proper housekeeping around rig
Is mandatory for next wells to flush cement unit line before start displacement to avoid get cement above float collar
Before rig acceptance these issues need to be addressed and ensure it in place, after that it cause a lot of time waste to fix. Run shock sub in 17 1/2" Drilling BHA. - To ensure bell nipple & flow line been install prior 159
NP_GX34_MI Drilling Program_WDI-840 13-5/8" BOP
surface observed scratches on top side of the test plug. Found some small pieces of metal drop (from Iron Roughneck dice) fall into wellhead while working & pressure test BOP. - Mobilized senior Wellhead Engineer to rig location for physically checked the damaged on wellhead.
Ru-443
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Ru-443
floor, frequently conduct the drop object hunt around rig floor. - To put cover on rotary table while working on wellhead & BOP to avoid any debris fall into the well.
to pressure test BOP (to avoid any debris on top of annular drop into the hole). - To consider a back up set of wellhead available at rig site.
- Mobilized senior Wellhead Engineer to rig location for physically check the damaged on wellhead.
While drilling 12 1/4" hole encountered 2 main rig engine failure and unable to apply full drilling parameter while drilling. Turbo charger of engine is overheated and it required to be shutdown.
Ensure WDI strictly follow the Preventive and Maintenance System for rig critical equipment which require schedule check and servicing. Ensure experience electrician available at rig site to troubleshoot the problem.
To perform engine load test during rig acceptance prior to spud the well.
Drilling 12 1/4" hole
While drilling 12 1/4" hole to 1021m, TDS suddenly tripped. While driller pick up of bottom, string spun to the left rapidly and observed string weight dropped from 144 Klbs to 72 Klbs and pressure decrease from 1700 psi to 550 psi. Look like string back off mechanically. Electrician found some grounding in chopper circuit and rectify the problem by replaced the chopper circuit completely & thermostat switch in TDS control room.
Driller need to promptly notify Electrician and DO NOT pick up of bottom. Continue circulate hole with drilling rate. Once TDS back on power, only then slowly pick up off bottom and monitor if anomaly observed (i.e string weight, SPP, Torque etc).
Put hydraulic brake in "ON" mode so even TDS power is gone it will prevent the string to rotate left. DSV to notify Toolpusher & Driller, when TDS is tripped, DO NOT Pick Up off bottom, keep circulation, once TDS back to power, slowly release the torque limit on TDS. WDI Electrician need to fix and resolve TDS issue before continue drilling if happen again in future.
Drilling 12 1/4" hole
While drilling to 1128m, Rig engine #2 caught fire, shut down the rig and observed fire flames moving toward engine #1 and #3. Rig firefighting team managed to control the fire. Isolated the rig engine room and found engine #2 and #3 is damaged. Wait and replaced the damaged engine with new engine. Found homemade modification on engine and not been
- All the modification and servicing of critical rig equipment need to be updated on the WDI PMS record. - To function test critical rig equipment (engine, TDS, Mud Pump) under load and certain period of time before spudding the well. - Completed Halliburton Land Rig Acceptance Checklist prior to rig acceptance & spud the well.
- Conducted extensive fire drills on rig site for crew familiarization and improve they response. - Ensure the rig fire pump function properly. - Closed the investigation finding on the incident as required.
Drilling 12 1/4" hole
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NP_GX34_MI Drilling Program_WDI-840 recorded on WDI PMS. Always retract the tie down bolts after engaging the wear bushing
Ru-443
Ru-443
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Ru-443
Retrieve the wear bushing
-Standard instructions and procedure to be discussed with driller prior to retrieve the wear bushing.
Unable to install 9 5/8'' pack off
Piece of rigid centralizer was stuck in Lower ram cavity and as result the 9 5/8'' pack off bushing cannot be installed. It required to open the lower Ram and removed this piece of rigid centralizer. After lifting BOP stack, observed piece of centralizer on top of 9 5/8'' casing hanger.
Leakage in quick seal of cement head in 2nd Stage cementing of 9 5/8'' casing
Drilling 8 ½’’ hole section
Do not lay down cementing head after 1st stage cement job. We may damage the cement head seals while taking the cement head off and on again.
Drill 8 1/2'' hole with MMD65R PDC bit and revised BHA to reduce the torque and obtained very good ROP as compared to previous wells
- When the cement head was removed prior to rig down the OD system, then rigged up again, we may have damaged the cement head seals, as the cement head leaked when pressuring up the DV closing plug. - Cementing team to ensure new seals is installed in cement heads prior to sending to location. Avoid using the rigid centralizers in casing x casing.
Casing Overdrive system is to be rigged down upon completion of the cement job of two stages.
- When the cement head was removed prior to rig down the OD system, then rigged up again, we may have damaged the cement head seals, as the cement head leaked when pressuring up the DV closing plug. - Cementing team to ensure new seals is installed in cement heads prior to sending to location. Use MMD65R PDC bit and same BHA in other future vertical wells
Casing Overdrive system is to be rigged down upon completion of the cement job of two stages.
Ru047A
Drilling 17 1/2" hole
Caliper log run in this section showing large wash out in 17 1/2"
Drill as fast as possible with high flow rate (3200-3400 lpm) in order to clean the hole and avoid wash out the unconsolidated rocks
Ru047A
Drilling 17 1/2" hole / circulation
Circulation rate is limited by the shakers flow capacity, maximum 2800 lpm,
Use API 80 screens, review the shakers set up and inclination to maximize the capacity of
Ensure spring bow type centralizers are installed in casing string.
Review parameters for next wells
Review with drilling contractor
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NP_GX34_MI Drilling Program_WDI-840 rate
otherwise it will overflow and mud will be lost on surface
handling high flow rate
Cured the losses in Dammam with 4 cement plugs:
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Curing losses in Dammam
Curing losses in Hartha
First plug placed on bottom, second one on top the first one and third at the same depth of total losses. No DH losses. While drilling formation with directional BHA observed severe losses. POOH to set 4rd cement plug
Partial losses while drilling at 1785m, rate 5 m3/hr
If tag the TOC plug close to the top of thief zone, is an indicator still we have a weak point; it should be pumping another plug before resume drilling.
Cured the losses in Hartha with 69bbl of 1.62 sg bentonite cement, the cement held well during drilling and cementing
1. Baroid to check the chemicals to be free from gravel by doing samples and tests before sending it to the rig, this way we can eliminate the risk of having problems with mud and plugged string.
Drilling operation in Hartha formation
Stand pipe pressure unstable and very poor MWD decoding, SSP increase suddenly around 400 Psi. After checking observed DP screen plugged with gravel, due to big bags bentonite containing gravel.
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Flow from annulus 13 3/8” & 9 5/8”
Record 77 bbl of losses during displacement in the second stage 9 5/8” cement job. Kill the well by bull heading with 110 bbl of 1.14 SG and perform cement top job with 179 bbl of 1.9 sg
Flow from Dammam, formation kept expose after loss the hydrostatic column
Ru047A
FIT failure in 9 5/8” casing shoe in Sadi
Drill out (DV, baffle, cement and rat hole) plus 3m of new formation in 7.25 hrs.
1. Casing shoe was set 5m from bottom (5mt of rate hole).
Ru047A
2. WDI to Make dead volume at least 1 foot, because the mud system suck from the bottom of the suction tank direct. This lesson already raised from Ru-441
1. Should tag TOC plug 15-20 m as minimum above the thief zone to avoid any weak point. 2. A new decision tree for curing losses in Dammam was created (more volume to be pumped). To be apply in next wells. Use the same slurry design for next wells
1. Raised the problem to Baroid to check the chemicals to be free from gravel by doing samples and tests before sending it to the rig, this way we can eliminate the risk of having problems with mud and plugged string. 2. Raised the problem to WDI to Make dead volume at least 1 foot, because the mud system suck from the bottom of the suction tank direct. 1. Ensure good seal in Dammam while losses are curing. 2. Applied decision tree for curing losses in Dammam 1. In future, ensure rat hole do not exceed more than 2 m 162
NP_GX34_MI Drilling Program_WDI-840 formation After 65.5 hrs from cement in place, tried to perform FIT in 2 times without success. Decided squeeze cement job
Ru047A
Drill 8 ½” hole section
Performed directional work dropping angle from 10 deg to 0 deg at +-2170m
2. Probably leak in surface equipment at the time to perform the FIT. 22 horas later attempt to perform squeeze test and observed the pressure build up to 970 psi and stable for 20 min. Pressure test accepted by ROO as FIT.
From 2165m to TD, drilled section just in rotary mode (good tendency of formation to maintain verticality with the BHA designed) High ROP in 8 ½” = 12.7 mt/hr
Ru047A
Poor quality of cement CAST log in 9 5/8” casing
Record losses during displacement of second stage cement job. Contaminated mud and spacer in surface
No cement in Dammam. Is necessary to re-design the cement job procedures and slurries
Ru-
Fishing wireline tool
While logging with GR-SDLTDSNT-CSNG-WSTT, the tool
1. Tool got stuck differentially
2. Ensure cement pumping unit and lines are properly pressure tested before performing FIT 3. Ensure valves and lines from cement unit to BOP are in good condition. 4. Inspect all equipment including valves to found out any pressure loss. Daily greasing and maintenance. Once the well reach verticality, continue drilling in rotary mode until total depth (considerer target box 100m x 100m) and continue with the same BHA design for next wells 1. Place 2 Cement basket between 95/8” x 13-3/8” casing: one to be located 10m above previous casing shoe and second one close to surface (50M – 100m) 2. Possibility to be used “Foamed cement slurry” (low density and higher density). Prevention from cement volume loss to the formation, better fill-up cavernous zones, short transition time and provide earlier compressive strength on the surface. Option under study by Cementing team 1. Re design the 163
NP_GX34_MI Drilling Program_WDI-840 047A
Ru047A
in 8 ½”
7” Cementing plug did not bump on float collar. Cement slurry was under displaced by 24 bbl (193m of cement inside 7” casing above float collar)
stuck at 2630m. Worked on stuck trying to release the tool; decided to fish by cut and thread operations
2. All the over pull reported are in the area of washouts (35 to 50 m length – OH 9.5 – 11 in). Tool length was smaller than the washout area, tool can be mechanically stuck. 3. No proper reaction of Wireline winch man to prevent the tool stuck 4. Lack of procedures to proceed in case observe poor hole condition while logging
With casing on bottom, circulate to clean hole by 3 hrs with 1100 lpm and 1300 psi. No losses reported.
1. Possible pack-off while start Slurry displacement; pressure increase 2000 psi above expected pressure with the slurry still inside the casing.
During 7” cementing job, recorder 8m3 of losses during pumping cement and 5.5 m3 while displacement. Final circulation pressure was 4300 psi (1500 psi more than final pressure of design)
During running Basket, tag @ 3193m – Float collar @ 3386 (193m above float collar) • •
•
Total losses = 13.5 m3, 85 bbl Theoretical displacement as per program to FC = 413 bbl Real displacement (As per Top of plug tagged with Junk Basket/gauge ring: ~ 389 Bbls
2. Mud pump efficiency taken during wiper trip prior to run casing of 97% Miscalculation of fluid displacement might be the result of change in pump efficiency at high pressure (3500 psi while displaced with rig pumps). Probably mud pump efficiency during displacement was 91% 3. Compatibility of fluids and field samples of preflush/slurries had being tested in lab to discard any deviation from design properties and fluids compatibility, the results matching with pilot test running ahead of the job
wireline logging length (make it longer) if caliper log shown big washout interval 2. Re-Train the personnel in charge of Wireline unit operation in the contingency procedure 3. Close Calipers in interbedded areas – high washout areas 4. Close pads without field approval in case of over pull more than 2000 Lbs is observed.
1. Do not spot hi-vis on bottom prior to run 7” casing during wiper trip 2. Circulate the active drilling mud to achieve YP below at18. No pre-mixed and pump low rheology mud prior cement job 3. While running casing: Break circulation at the 9 5/8 shoe and every 500m. Circulate bottoms up in the top of Tanuma, Mishrif and Zubair and record pressures A torque & drag sheet from well plan is to be done for running casing and followed real time on the rig this may highlight any potential areas that need circulation while running in the hole Hook load records while running casing 164
NP_GX34_MI Drilling Program_WDI-840
(real vs calculate) and compare with torque & drag sheet from well plan. Ensure the mud pump efficiency is correctly measured during wiper trip and running casing
4. Tag bottom with casing prior to pick up casing hanger and circulate hole clean (circulation rate cannot exceed the ECD while drilling). 5. Reciprocate the string and monitored the pressure at start and the end of circulation. 6. Space out, set casing and install cementing head, circulate through cement head to hole clean more (more than 2 bottoms up) and compare pressures with last circulation 7. Use the cement unit for displacement all volume to avoid the occurrence on cement left inside due to inefficiency of rip pumps 8. Design tail slurry with low fluid loss value , ~ 35 – 40 cc and continued with inhibited fluids for the slurries7” 9. Batch mixed in tail slurries to achieve better cement bonds
Ru-450
Working on BOP and Wellhead
One of BOP bolt got stuck while screw in then rig crew tried to close by hammer wrench and by hammering
- WDI need to create an specific Standard Operating Procedures (SOP) for removing & installing bonnet
- WDI will be updating the SOP folder on the rig site for crew reference. 165
NP_GX34_MI Drilling Program_WDI-840
Ru-450
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Ru-450
Cure Losses in Dammam
Drilling 12 1/4" hole
Running 9 5/8" casing
but no success. To investigate the situation, STP open the bonnet again and found some of threads are galled/damaged inside the box in BOP Ram Bonnet which not allowing the bolt to screw in. This has caused the internal thread damage on BOP rams body for bonnet bolt.
bolts and include the specific equipment information.
Cure losses in Dammam with 2 cement plug
Blind drilling to 15m below the total loss depth. Then set the 1st cement plug with big volume of 60 – 64 m3 (360 400 bbls)
Updating the Dammam flow chart strategy & continue to implement this procedures on next well
While slide drilling to 1531m, observed intermittent pulses occurred led to detection lose. Operate and troubleshoot the MWD tool a flow rate range of 2400 lpm to 2700 lpm, then shaking string updown however the pulses were entirely flat and no success. Finding on the incident, pulsar exposed to mud invasion thru Top end where under microscope they found sand/mud in the MWD oil.
Intermittent pulses continued with lost detection in spite of applying all troubleshooting procedures. Notify office & DSV eventually decision has been taken to POOH to change MWD tool.
Send the tool to Sperry Burjesia base for further investigation and checking the tool. Pulser MK10 (11815581) has been send to Dubai for repair and further investigation.
Encountered losses at 1660m (Hartha Top at 1736m) while running 95/8" casing.
- Closely monitor the running speed of casing while approaching loss zone of Dammam & Hartha. Recommended casing speed of 5 min per joint from 100m above loss zone to 30m below loss zone. - Pumped 15 m3, 40 lb/bb l () LCM and continue displacing with mud 1.14 sg while RIH casing - If encountered losses during drilling in Hartha, run MSIPC (packer type DV) instead of normal DV. - Additional chemicals and cement to be mobilized to locations so that incase of
- To be implemented on all future well as required.
- SOP will cover the responsibilities of who will be required to Supervise the job and will perform the critical part of the task- (STP & NTP).
- Communicate and share accident throughout the rig operation
166
NP_GX34_MI Drilling Program_WDI-840
Ru-450
Well Flow
After retrieving 9 5/8'' landing joint, observed well flowing. SICP-70 psi in. Mixed mud and kill well by bullhead through 13 3/8’’ x 9 5/8’’ casing annulus. The reason for well flowing was the losses in 9 5/8’’ casing cement job as 5m3 losses occurred in 1st stage cementing and 69 m3 losses occurred in 2nd stage. Circulate while RIH casing at every 500m and below washout area.
losses while cement job, additional volume can be pumped in lead slurry of 2nd stage. Bull head 24.6 m3, 1.25 SG mud in 9 5/8" x 13 3/8" annulus @ 400 lpm, 220 - 90 psi through kill line by cementing pump. Stop pumping observed 0 psi SICP
In case of losses while cement job in 9 5/8’’ casing cementation, always monitor the well from annulus for 30 minutes before proceeding to other operations
lessons learnt improved the cement job execution process
Continue the same practice for future wells.
Observed some restriction on 20" float shoe while passing with String stabilizer.
After completed cementing the 20" Conductor, drill out 20" shoe track with 17-1/2" bit to 1m new formation.
To drill 20" float shoe and 1m new formation on future well prior small rig release from location
Ru-456
Release OEDP's string with 240 klbs after placing LCP #3
Thixotropic slurry have high gel strengths and require shearing by rotation of string in case high level of cement in annulus
Rotate the string while place Thixiotropic cement to avoid the build up on the ge strength. Quickly move the string after complete placing the cement plug. Check & confirm the Chloride content on water to avoid water contamination (Cl should be 400 - 500 ppm)
Mud engineer to check Chloride content on the water before store it on cement tank.
Ru-456
Troubleshoot & fix TDS
Encountered frequent power trip on TDS
Rig contractor to properly maintain and servicing the
Rig contractor to replace the service loop on the
Circulate at bottom with YP of mud greater than 18 lb/100 ft2 till pressures are stabilized Ru-450
Cement 7’’ casing
Displace cement with cementing unit due to better pump efficiency and to know the exact volume for displacement and bump plug is closely monitored. Flush the lines with water before dropping top plug so that there is no cement behind the top plug.
Ru-456
Enlarge the compression of 20" float shoe
167
NP_GX34_MI Drilling Program_WDI-840 critical rig equipment as per Preventive & Maintanence System (PMS) to minimise the downtime/breakdown
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Hard Back Reaming during wiper trip
Make up 9 5/8" Shoetrack
Drill out MSIPC plug & Shoetrack
Replaced Module of Mud pump
TDS with new one
Excessive time to perform the wiper trip due to hard back reaming from 1940m to 770m which contribute to additional condition trip with new BHA
To reconfigure the drilling BHA by reducing the size of Near Bit & String Stabilizer by 1/8" instead of current configuration of 1/16".
To be implemented on future vertical well
Cross thread while make up float equipment (FS & FC joint) with ITS CRT-FMS due to mast alignments with rotary table. Laid down the damage joint and pick up the back float equipment.
Toolpusher, DSV & casing running crew supervisor to check and verified the alignment between Mast & Rotary Table. Make up the float equipment by using power tong and stabber to assist casing alignment for first few joint (5-10 joints) before using CRT-FMS.
To be verified and implemented on all future well
Observed no progress of drilling MSIPC plug with PDC bit after 4 hrs. POOH to pick up Tricone bit.
By using the Serial Number of Plug & MSIPC, trace the tool manufacturing process & technical specification with CMT team from, it confirmed the MSIPC plug is PDC drillable.
As contingency plan, DSV to ensure 1 x 8-1/2" Tricone bit available at rig site prior to drilling 8 1/2" hole whenever MSIPC been run on 9 5/8" casing.
Some of the tighten screw on Module #1 of Mud pump #2 been shear and causing it leaking
WDI to frequently check and inspect the tighten screw on Module of mud pump if it been loose over the time due to mud pump vibration
Prior to rig acceptance, DSV to ensure minimum critical rig equipment available at rig site store to avaoid longer waiting time for the spare part coming from WDI central warehouse. Perform mud pump servicing while POOH DP inside casing Assign 1 floorman to check mud pump every half an hour during drilling
Ru-456
Replaced leak IBOP with new IBOP
Observed leaking in IBOP on TDS while drilling 8 1/2" hole
WDI to strictly follow their Preventive & Maintanence System (PMS) for the rig equipment
DSV to check the WDI PMS prior to Rig Acceptance
Ru-456
Drilling 8 1/2" hole
While drilling 8 1/2" hole to 3068m, observed ROP dropped to below 2 m/hr.
To use a proven bit track record of MMD65R to drill 8 1/2" hole section in order to
To be implemented on future well 168
NP_GX34_MI Drilling Program_WDI-840 Performed drill off test at different drilling parameters without any improvement on ROP. POOH to replace the bit and on surface observed bit is worn out.
Ru-456
Ru-456
Ru-456
8 1/2" Openhole logging
8 1/2" Openhole logging
Running 7" Casing
Observed Micro Resistivity log (MSFL) not working while checking tool signal at 9 5/8" casing shoe.
After tag bottom at 3401.5m, record the main pass. Observed SDL Caliper (Density log) not open. Troubleshooting for SDL caliper but no success.
Changed the battery of CRT system for transmitted torque reading by Wi-Fi signal between CRT and Jam Unit.
achieve 1 bit from shoe to shoe.
WPS to ensure all the logging tool leaving base camp to rig site has been checking & function test properly. DSV to verify the WPS equipment checklist been completed once arriving the rig location.
POOH to surface and replaced the tool with back up tool. Wireline crew to verified & confirm that tool has been inspect and function test prior to the job.
WPS to ensure all the logging tool leaving base camp to rig site has been checking & function test properly. DSV to verify the WPS equipment checklist been completed once arriving the rig location.
Completed the Image log in Zubair & Mishrif formation then then POOH to surface to replace the SDL logging tool with back up unit. Rerun SDL log (CSNG-DSNSDL) to record log in 8 1/2" openhole.
Prior to sending the tool to rig site, ITS need to ensure the battery is new for the CRT system and battery life sufficient to cover the whole duration of casing running job.
DSV to ensure this new battery requirement been checked & added on the ITS equipment checklist & also have additional battery as back up.
Ru-458
13 3/8" Cementing casing
Was observed 6m3 of losses during cement displacement. No cement in surface, was necessary perform top job
Slurry design with 60% of excess. This well is located close to north of Rumaila field
For next wells, to continue with 100% of excess. Ensure cement in surface and avoid to perform top job
Drilling at 625m observed total losses, drill blind up to 645m and pumped 2 cement plugs, drill out up to 642m where observed total losses again; pumped 3 cement plugs more
Drill blind more than 15m once losses appear. If is possible, drill blind up to top of Rus formation.
Pumped 5 cement plugs to cure losses in Dammam
Ru-458
Pumped 5 cement plugs to cure losses in Dammam
Accidentally Sidetraking
During drill out cement plugs, observed 100% of formation in returns. Used to drill out a tooth bit - IADC 137
Continue with Tricone insert bit to perform drill out. Do not use tooth Tricone bit
To be apply in next wells
ROP decreased from 10 to 2.5 m/hr drilling
Due to low ROP, POOH to check 12 1/4'' PDC bit. Observed drill out on bit. Dull grade: 5 -2–RO-N -X -IN
Drill 12 1/4" section with bit SF66DH type (6 blades, 19 mm, dual row backup cutters). In previous wells, had good
Do not changes bit type. To be apply in next wells
Ru-458
Ru-458
169
NP_GX34_MI Drilling Program_WDI-840 at 1815m.
-LT-PR.
results with this bit type
Bit used SF65H (6 blades, 16 mm cutters). Observed high torque with high parameters while drilling . BHA rotary
Ru-458
Hard Back ream and string got stuck while POOH 12.25" packed BHA
During pull out trip due to low ROP, pull out with hard back reaming from 1618m to 1468m in Shiranish (tight hole) and Tayarat
To use stabilizers under gauge to drill 12 1/4" section, regardless hole is vertical or directional. Wash up and ream down one single every stand drilled and ream down full stand while drilling Shiranish.
Design the BHA for this section with stabilizers under gauge size
Treat active system to drill Hartha fm with LCM
As per NDS file, offset wells showed partial losses in Hartha. Was include PBL tool in the BHA as contingency and treat active system with bridging material for Hartha formation ( STEEL SEAL + BARACARB 25 + BARACARB 150 ).
Mitigate successfully down hole losses by preventive treatment with Bridging LCM material
Treat active system to drill Hartha formation with LCM
Continue with practice to ream up and down one single every stand drilled to avoid wash out
To be apply in next wells
Clean mud tanks after finish 12.25" hole section and dump all mud that have LCM on it, clean and flush mud pumps and surface lines prior RIH with 8.5" BHA. Don’t use old mud from 12.25" section if it contaminated with fine LCM.
To be apply in next wells
Ru-458
Ru-458
Caliper log in 12 1/4"
String plug due to poor cleaning mud tanks
Caliper log showed average hole size 12.54 in, it means only 2.36% washout. RIH with directional BHA to 391m, tried to fill up string and observed pressure build up to 1000 psi, check surface lines and pumps. String plug.
Ru-458
Prior to mix the new fluid and before the displacement, ensure all mix lines and pits are cleaned and flushed with fresh water
Ru-458
Tried to drill out MSIPC with PDC bit, no success
The MSIPC opening plug that was ran in the hole was cast iron type, which is not drillable with PDC bit.
To verify and confirm with cementing team that MSIPC opening plug is PDC drillable, it means "Composite type"
Check the specifications of every element from cementing workshop and confirm the type of assembly will be send to the well 170
NP_GX34_MI Drilling Program_WDI-840
Ru-458
Failure in 9 5/8" casing pressure test
Tried to perform pressure test (three times) up to 2000 psi, no success. Leak in surface.
Perform pressure test after drill out MSIPC and prior to drill baffle plate to ensure all barriers casing integrity
Evaluate the option to casing test with 1500 psi
Replace MSIPC by conventional DV tool
Over hydrostatic pressure is generated by the tail slurry vs formation pressure due to close system by inflatable packer element in MSICP. This over pressure can generate invasion to the formation causing cement contaminated and don’t show cement bond in CBL log.
Replace MSICP by DV tool to avoid over pressure in close system that causing cement contaminated.
Evaluate the option to run just DV tool in net wells instead of MSIPC
Microannulus in tail slurry first stage
Casing was tested four times trying to reach 2000 psi. FIT was perform with 900 psi. That operation could be generate high microannulus affecting the cement bond
Test the casing right after cementing while cement is still green, after drilling the DV tool test to 1500 for 15min
Discuss with ROO the pressure test requirement for the casing
Cementing 7" casing
the CBL-VDL shows galaxy patterns in the space between 9 5/8" and 7", this is a result of touching between the two casing due to lack of centralization in cased hole
improve the centralization in casing x casing space by increasing the number of centralizers (3 x jts)
To be applied in next job
Running 3 1/2" tubing
while running 3 1/2" 9.5# L80 one of connections was over torqued, while trying to pass with 2.81" gauge cutter faced obstruction and could not pass, POOH and examined the connection, observed lips deformed toward the inside of tubing, drifted the tubing without success
closely following making up connections while RIH with tubing and make sure to not approach maximum torque, the connection should be torqued to optimum torque
To be applied in next job
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Ru - 463
Cure Dammam and Hartha losses
Cure losses with new slurry design of 1.50 sg and High YP >60 slurry
The new slurry with High YP with 1.50sg resulted in controlling the losses with 2 cement plugs. Volumes of plug limited to 30m3 for first cement plug with total losses Volume of plug limited to 20m3 for 2nd cement plug with total losses Volume of plug limited to
Pumped two cement plugs of 30m3 and 20m3 to cure losses.
171
NP_GX34_MI Drilling Program_WDI-840 15m3 for 2nd cement plug with total losses
Ru - 463
Ru - 463
Ru - 463
Do not pump Hi-Vis pill between Dammam & Hartha
Eliminate practice to pump Hi-vis pill every stand drilled in order to avoid differential pressure in well's hydrostatic column
Pump Hi-Vis pill to circulate to clean out.
To be apply in next wells
9-5/8" casing cement job
Excess in open hole was chosen correctly. Observed lead slurry 1.45 SG to surface using 20% Lead excess and 10% Tail excess above caliper.
Continue using 20% Lead excess and 10% Tail excess above caliper in upcoming 95/8" casing cementing jobs
Continue using 20% Lead excess and 10% Tail excess above caliper in upcoming 9-5/8" casing cementing jobs
Continue using two cement baskets. One – 10 m above previous casing shoe, one – 10 m below the surface to ensure cement will not fall back into Dammam formation which is very weak
Continue using two cement basket in 9-5/8" casing cementing job
Cement above DVT while cementing 95/8" casing
During 9-5/8" casing cementing job, bring the Cement of the 1st stage 100m above the DV helps to have good cement around the DV tool. In addition, the contaminate cement with mud reached higher depth and it was circulated after opening the DV tool.
During 9-5/8" casing cementing job, bring cement of the 1st stage 100m above the DV tool.
9-5/8" Casing test
Two CBL-VDL-CAST logs were RIH, before and after testing 9-5/8" CSG. It was proved that the casing pressure test have an effect in Cementing job isolation
RIH CBL-VDL-CAST logs before pressure test 9-5/8" casing
All injector wells within 500 m radio need to be shut-in before drilling Dammam formation. There is one Dammam injector well (Ru294), 313 m away from Ru463 which probably was not shut-in while drilling Dammam formation, and some influx was observed while drilling Dammam.
Ensure all injector wells within 500 m radio are shut-in before drilling Dammam formation
While trying to cure losses
There should be sufficient
Cement baskets in 9 5/8”
Ru - 463
Ru - 463
Ru - 463
Ru - 463
Injector wells
Mud quantity
To be apply in next wells and included in the cementing program
To be apply in next wells and included in the cementing program
To be apply in next wells
To be apply in next wells To be apply in next wells 172
NP_GX34_MI Drilling Program_WDI-840 to pump LCM pills in 12 ¼”
in Hartha, it was spot 15 m3 of LCM pill. Activated PBL sub and pump15 m3 of LCM pill, displaced pill with1.13 sg mud by string volume. While waiting on LCM to soak, observed run out all the mud in system. There was not sufficient prepared mud in the tanks to be able to filling the well. Continuous total losses in Hartha, consumed planned mud in the system, after pumping LCM pills. Waiting 2.5 hrs to have 1.14 sg new mud available in the system.
mud volume in the tanks to be able to pump ~ 20 m3 of LCM pill and be able to keep filling the well while total losses in Hartha. There should be at least 70 m3 (16 m3 (one string volume) x 3 = 48 m3 + 22 m3 (including dead volume)) of mud in the tanks to be able to pump LCM pill and keep filling the hole.
Ru - 463
Continue circulating to avoid string plug
While trying to cure losses in Hartha, the string got plugged after pumping 4 m3 of 1.14 sg new mud. After POOH and LD, observed min quantity of fine LCM on top of the MWD.
After pumping LCM through PBL should continue circulating once POOH to clean pipe and minimize the possibility of settling.
To be apply in next wells
Ru - 463
High viscosity slurry for cement plugs
For cement plugs, use high viscosity slurry to increase the friction in the fractures to plug with cement.
For cement plugs, use high viscosity slurry to increase the friction in the fractures to plug with cement.
To be apply in next wells
Caliper log
It’s recommended to continue running caliper log (6 arms) before each cement job which will lead to rational use of cement slurries and promotes to meet Zonal Isolation Standards
Continue running caliper log (6 arms) before each cement job
Ru - 463
Ru - 463
Use Defoamer in 7" casing cementing job
Ru - 463
Frac tanks for cementing jobs in 7” csg
Ru - 463
RIH 7" casing and expected
To be apply in next wells and included in the cementing program
Observed foam in mud while displacement cement in 7" casing cementing job.
For future 7" cementing job is recommended to use a defoamer when using cementing unit to displace the cement in 7” casing
To be apply in next wells
While cementing 7" casing, it is recommended to have a more accurate measurement for counting displacement volumes.
Use frac tanks for displacement of cement while performing casing cementing jobs, in order to have more accurate displacement volumes.
To be apply in next wells
While RIH 7" casing, it was observed high pressure
Pressure should be reduced to expected pressure before
To be implemented in next wells. Run hydraulics 173
NP_GX34_MI Drilling Program_WDI-840
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Ru-465
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pressures
while circulating @ 3075 m prior entering Middle Shale formation. The string was reciprocated while circulation, and the pressure was reduced to 2200 psi. However, the expected pressure at that point should be around 11001150 psi according with hydraulics simulation. 7" casing was continue running in hole regardless the pressure was still higher than expected. Pressure should be reduced to expected pressure before continue RIH casing.
Caliper log in 8-1/2"
Caliper log showed average hole size 8.81 in, it means only 3.67% washout.
7" Casing running speed
7" casing was RIH according to casing running speed program to avoid surge the well.
continue RIH casing. Reciprocate string while circulation and reduced pressure to expected pressure before continue RIH Casing.
simulation for running casing and keep sending the same to the rig. Ensure instructions are followed at the rig site regarding real pressures vs expected pressures while RIH casing.
Continue with practice to ream up and down one single every stand drilled to avoid wash out
To be apply in next wells
Continue sending casing running speed program to the rig site to avoid surge the well. Ensure the program is followed closely and all the casing joints are run with the correct speed.
To be apply in next wells
RIH with cement stinger to tag cement plug
After spotting lost circulation plug , POOH inside 13 3/8" casing flushed the string and WOC. After WOC RIH 4 stands and tried to establish circulation, observed pressure build up, POOH 2 stands, attempted to establish circulation and had same build up in pressure. POOH 5" stinger to surface, found 7 stands plugged with cement inside. Then stinger was clean.
After waiting on cement, RIH with circulation to avoid cement entering into the DP. Calculate the estimated TOC of cement according to the volume pumped and volume returned, POOH at safe distance from top of cement
Hard back reaming during wiper trip
Drilled in 12 1/2" section up to 1721m - 23m above top of Hartha and performed wiper trip with hard back reaming from 1633m to 1100m in 51.5 hrs. Decided POOH to surface and check
Wash up ream down 2 times full stand instead off one single while drilling every stand in directional wells with angle higher than 20 deg.
Implemented in next plugs job, RIH with circulation
In directional wells with angle higher than 20 deg, add to active system 1% of lubricant once loses are cured in Dammam (from Rus to TD)
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NP_GX34_MI Drilling Program_WDI-840 directional tools and bit.
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Ru-465
Losses in Hartha
Drilled from Hartha to section TD at 1962m in rotary mode
Prior to enter to Hartha formation, the active system was treated with bridging material (steel seal 400 and baracarb 50) to mitigate losses in Hartha. Observed partial losses 12-15 m3 which were cured with LCM pills through PBL tool After wiper trip, was changed the mud motor BH to 0 deg. RIH and drilled in rotary mode from 1721m to 1962m; the well dropped 8.49 deg of inclination in rotary mode within 154m (from 1808m top of Hartha to section TD and from 22.45 deg to 13.96 deg). Was not possible to do any correction of direction and inclination.
Pump LCM pills of 120 ppb through PBL once losses are observed. Treat the active system with 40 ppb of fine and medium bridging material
To be applied for next wells
Once started to drill in 8 1/2" section was necessary to make corrections of inclination and azimuth to conduct the well in the correct position into the Sadi formation
Do not change the motor BH to 0 deg. In case to observe losses while sliding, stop the drilling and cure losses through PBL and continue with drilling in rotary mode
Distance to plan: 18.63m. Projection to TD: outside from target tolerance of 50m
Ru-465
Good cement bong results in 9 5/8" casing
During the 2 stage cement job, was pumped an additional volume over plan (60 bbl in tail and 46 bbl in lead slurry) as contingency in case to observe losses during pumping and displacement of cement. No losses while pumping cement, 5 m3 at the end of displacement.
Ru-465
Measure of ID casing
During displacement of cement in 2sd stage was observed a difference between total volume pumped (10 bbl additional) and volume of displacement planned.
Run CAST log and observe good results (best cement bond results so far in drilling campaign - 10 wells drilled) * 1st stage: cement volume (must be batch mixed – around 100 bbls – sg = 1.75 ) * 2sd stage: 15% of excess in tail and TOC ~350m above Tayarat and 50% of excess in tail 3 joints de shoe track y 3 cement basket * 3 joints of shoe track * 3 cement basket between casing - casing Besides to measure the length of each joint is necessary to measure the ID of casing in order to ensure a volume of displacement more accurate
To be applied these recommendations for next wells
To be applied these recommendations for next wells
175
NP_GX34_MI Drilling Program_WDI-840 ID measured = 8.75in average in 20 joints ID 9 5/8" 47#/ft = 8.681 in
Ru-465
Good performance while drilling in rotary mode in whole section
Good performance of drilling, high ROP and hole in good conditions after run Caliper log
Applied optimum drilling parameters WOB: 10-15 Klbs, Surf. RPM 60, FL: 2000 lpm, Dif press on motor=200-350 psi ROP: 20-30 m/hr
To be applied these recommendations for next wells
Ru-465
RIH 6'' gauge ring and junk basket inside 7'' casing
Junk basket full of contaminated cement when POOH to surface. Additional run required to confirm no cement on top of float collar.
Give enough time for cement to set perior to RIH junk basket.
Ensure cemment is set from UCA chart prior to run slick line.
Observe Down hole losses from 9 m3/hr to 15 m3/hr. Pump total 58 bbl of Sentinel Cem Slurry 1.2 SG, 10 ppg at 2-5 bpm by cement unit, when SentinelCem slurry reaches the bit atfter pumping 30bbl, shutdown and close annular BOP. Inject the rest of 28 bbl of Sentinel Cem Slurry 1.2 SG, 10 ppg at 2- 4 bpm by cement unit. Cure losses in Dammam, No DHL observed. Mud was conditioned with YP of 18 lbf/100ft2, circulated enough time for second stage ensuring that the mud is as per requested properties.
Continue pumping SentinelCem to cure losses in Dammam. Follow SentinelCem operational procedure in detail.
Implement procedure and train cementing supervisor.
Continue keeping YP below 20 lbf/100ft2 (18lbf/100ft2 Optimal) and circulate for second stage ensuring the mud is as required.
Continue same good practice.
Cure Dammam Losses
Ru-468
Ru-468
9 5/8" Casing cement job
Ru-468
RIH 3 1/2" Tubing
Ensure 3 ½” DP tally is distributed to all parties prior starting RIH. Ensure driller’s pipe-tally and the mud-logging tally depths align correctly before tagging FC/Cement and that the DSV is present on the drill floor at the determined critical wash down point.
Instruction added to future drilling programs to tag the PBTD with no more than 2-3 klbs. The forward plan will also be communicated to the driller and all involved in the process with clear instruction will be given to take care when tagging on bottom.
Update drilling program
Ru-468
RIH 3 1/2" Tubing
Continue RIH 3 1/2” Tubing and 3 1/2” DP joint to 1 meter above cement / Float Collar (if any cement
Ensure that Halliburton DSV is on rig floor before pumps on to wash down and tag the PBTD with 3 ½” Tubing.
Instruction to be updated to rig crew.
176
NP_GX34_MI Drilling Program_WDI-840 observed with gauge ring). Don’t apply any weight on WLEG.
Ru-468
RIH Gauge cutter in 3 1/2" Tubing
After making up WLEG it will be drifted to confirm integrity: the drift run should be run 50 m below the tubing shoe.
DSV to witness the SL weight indicator. SL weight indicator should read the same string weight below the WLEG.
Instruction to be updated to rig crew.
Ru-469
Drill 12 1/4" hole
Introduced new bit design MMD65DMH matrix body with 6 blades and 16mm cutters, the previous bit SF66 series was more aggressive but had low ROP to drill from shoe to shoe. The new bit design is fitted with double row cutters and impact resistant features. Significant improvement to ROP (18.6m/hr) and less vibration were observed.
Continue trial for this bit in vertical and deviated wells as it has shown promising performance results. Design can be customized based on bit performance and dull grading.
Update drilling program with the new bit design
Ru-469
Cement 9 5/8" casing
After the achievement of the ZI criteria in R-612 using the 3 slurries system on the second stage of the 9 5/8" casing cement job. The aim was to continue test the new slurry and confirm ZI in the 9 5/8" x 13 3/8” overlap which was challenging during the offset wells. Performed the second stage using Lead 1 with Microlite P a cement extender and lightening agent instead of the Cenospheres. Lead 2 as per previous programs with Cenospheres and conventional 1.75sg tail. A scavenger was pumped as per previous LL.
Good results were shown from the preliminary CAST analysis, and it shows that the logging tool readings are improved by avoiding the Cenospheres inside the casing overlap.
Implement the new design to coming 9 5/8" cement jobs.
Ru-469
Drill 8 1/2" hole
The caliper logs showed very good 12 1/4" and 8 1/2" holes with 12.34" (