DwC Project Management the best practice
- 1. DwC Project Management Ming Zo Tan – Global DwC Product Champion Date: March 12-16th, 2012
- 2. Applications Engineering Initiate Customer Contact BD/Sales Product Line Manager 1.1 Request Detailed Job Data BD/Sales Customer 1.2 Client Meeting Record Data Request Form Data Review, Analysis and Mechanical Feasibility Study BD/Sales Applications Engineer 1.3 Offset Bit Records Sonic, Mud, Density and Caliper Logs Seabed Survey Digital Drilling Parameters Offset Drilling Report Shallow Seismic © 2009 Weatherford. All rights reserved. 1 Parameters Report Rock Strength Analysis DwC Application? Submit Application Review Report Applications Engineer BD/Sales 1.5 Prepare Technical and Commercial Proposal BD/Sales Product Line Manager 1.6 Submit Finalized Job Order BD/Sales Applications Engineer 1.7 Analyze Economic Data BD/Sales Applications Engineer 1.4 DwC Proposal Economic Analysis Tool Hydraulics Calculation Job Order Form Application Review Report No Yes Torque & Drag Model Note: Drillability is determined by evaluating offset data. Quality and quantity will increase the accuracy of the report.
- 3. Decision Process Directional control required ? Candidate Well Vertical or tangent? Yes No Yes No Economic analysis Yes No Not Drillable © 2009 Weatherford. All rights reserved. 2 FE, MWD or logging required ? Top drive available ? More complex operations acceptable ? No Yes No Yes No No Engineering & Economics justifiable ? Drillability analysis Commercial proposal No DwC™ No Drillable Yes Yes Not Drillable
- 4. Decision Making Cheat Sheet Drillng with Casing Decision Making Cheat Sheet Section 1 Section Trajectory Question 1.1 Is this a vertical section ? Question 1.2 Is this a tangent section Question 1.3 Building to less than ?? degrees Section 2 Formation Evaluation Question 2.1 No logging required for this section Question 2.2 Required logging can be done through casing PASSED True False True False True False True False True False © 2009 Weatherford. All rights reserved. 3 Question 2.2 Required logging can be done through casing Section 3 Rig Equipment Question 3.1 Does the rig have top drive Question 3.2 Acceptable to use longer kelley and more complex operations Section 4 Drillability Question 4.1 Section length < 200m (656ft) Question 4.2 Lithology comprises of clay, loose sand Question 4.3 Sonic transit times > 100us/ft Question 4.4 Offset used IADC 1-1-5 / 1-1-7 to drill, ROP > 40m/hr (1312ft/hr) PASSED PASSED PASSED True False True False True False True False True False True False True False ..Drilling with CasingDwC™ Decision Making Cheat Sheet.xls
- 5. Project Flow Identify client and application DwC™ proposal is written and requires the following work: 1. Review well profile to determine if DwC™ is applicable 2. Formation Studies (review of offset drilling and wireline data. Calculate rock strength and drillability) 3. Review drilling rig specifications/capabilities (is the rig capable of operating a DwC™ system?) 4. Review casing program (is the casing proposed suitable for DwC™ ?) Contact client Client Enquiry Give DwC™ presentation Client request for proposal Data request to client Data valid /adequate ? Data analysis and feasibility Submit technical Visit customer to confirm understanding of the technical © 2009 Weatherford. All rights reserved. 4 Internal DwC™ report generated and entered into database and feedback to Global DwC™ DwC™ ?) 5. Tool selection (working out which DwC™ system is best for the job, do we have the correct tools?) 6. Confirm that all tools are available and can be delivered on time, redesign tools if necessary. 7. Price out the system 8. Write a customised drilling program/running procedure (all DwC™ jobs are unique) Consolidate field reports, write formal report and submit to customer Give information to accounts for invoicing Confirm equipment requirement Submit technical proposal to customer of the technical proposal, confirm price, deliverability etc Client awards work Review reasons. revisit proposal or drop Order equipment Mobilize equipment and personnel to location Run DwC™ job. Field personnel generate job report Demobilize and inspect equipment for damage
- 6. FORMS AND TEMPLATES FORMS AND TEMPLATES © 2009 Weatherford. All rights reserved. 5 FORMS AND TEMPLATES FORMS AND TEMPLATES
- 7. Economic Analysis COUNTRY WELL NAME CUSTOMER HOLE SIZE CONNECTION TIME DwC Conv. Drillpipe 25.0 Length / Std, m 12.2 30.5 Conn. Time / Std, min 5.00 4.00 Tripping Rate, m/hr 146 457 DP In, m - - DP Out/TD, m - 1,200 Round Trip DP Connections 0 78 DP Connection Time, hr 0.00 5.20 Csg In, m 300 300 Csg TD, m 1,200 1,200 No.of Csg Connections 73 73 Csg Connection Time, hr 6.08 6.08 Total Csg Running Time, hr 6.08 6.08 Csg Running+DP Conn. Time, hr 6.08 11.28 DwC VERSUS CONVENTIONAL DRILLING DwC Drill & Run Csg On Bottom ROP, m/hr 30.0 30.0 Total Drilled, m 900 900 Hours On Bottom 30.00 30.00 Csg Running+DP Conn. Time, hr 6.08 11.28 M/U and L/D BHA - 4.00 Prepare to Run Casing 1.00 1.00 DRILLING WITH CASING ECONOMIC ANALYSIS DwC Breakeven ROP, ft/hr OPERATIONAL TIME BREAKDOWN 6.1 11.3 0.0 4.0 1.0 1.0 1.0 3.0 1.0 1.0 0.50 - - - - - 30 40 50 60 HOURS Ver.7.0 Page 1 : Main Calculation Sheet Page 1 : Main Calculation Sheet Item Description Qty per well (estimated) Unit Cost US$ Total Cost US$ 1 7” Defyer DT 1.00 $32,000.00 $32,000.00 2 7” Float Collar 1.00 $700.00 $700.00 3 Spear Pack Off Rubber 1.00 $550.00 $550.00 4 Spear mob. / demob. 1.00 $2,000.00 $2,000.00 5 Spear rental per well (7 day lumpsum) 7.00 $706.00 $4,942.00 6 Redress Charges 1.00 $1,800.00 $1,800.00 7 DwC Supervisors mob. / demob. 1.00 $1,500.00 $1,500.00 8 DwC Supervisor service charge 4.00 $1,200.00 $4,800.00 $48,292.00 Total estimated DwC cost DwC ENGINEER AND SPEAR COST ESTIMATION Page 2 : DwC™ Cost Calculation Page 2 : DwC™ Cost Calculation Sheet Sheet © 2009 Weatherford. All rights reserved. 6 Prepare to Run Casing 1.00 1.00 Reaming 1.00 3.00 Circulate, Displ. Hi-Vis 1.00 1.00 DS3 Conversion 0.50 - Other NPT 2 - - Other NPT 3 - - Total Hrs 39.6 50.3 Total Days 1.6 2.1 ROP (incl. Connection), ft/hr 24.9 25.6 Rig Rate, USD/day $120,000 $120,000 Rig Rate, USD/hr $5,000 $5,000 Drlg Cost excl. DwC/Bit, USD $197,917 $251,417 Total DwC Cost, USD $48,292 $ - Bit Cost, USD - $25,000 Extra Savings, USD $ - $ - Drlg incl. DwC/Bit,USD $246,209 $276,417 Cost / m $274 $307 Saving $30,208 - 30.0 30.0 0 10 20 DwC Drill & Run Csg Hours On Bottom Csg Running+DP Conn. Time, hr M/U and L/D BHA Prepare to Run Casing Reaming Circulate, Displ. Hi-Vis DS3 Conversion Other NPT 2 Other NPT 3 Time Depth Curve 100 300 500 700 900 1,100 1,300 1,500 0.0 0.5 1.0 1.5 2.0 2.5 Days Depth, ft Conventional DwC Total cost from Page 2 is fed into Page 1
- 8. Economic Analysis OPERATIONAL TIME BREAKDOWN 6.1 11.3 0.0 4.0 1.0 1.0 1.0 3.0 1.0 1.0 0.50 - - - - - 30 40 50 60 HOURS 25.0 DwC Breakeven ROP, ft/hr DwC VERSUS CONVENTIONAL DRILLING DwC Drill & Run Csg On Bottom ROP, m/hr 30.0 30.0 Total Drilled, m 900 900 Hours On Bottom 30.00 30.00 Csg Running+DP Conn. Time, hr 6.08 11.28 M/U and L/D BHA - 4.00 CONNECTION TIME DwC Conv. Drillpipe Length / Std, m 12.2 30.5 Conn. Time / Std, min 5.00 4.00 Tripping Rate, m/hr 146 457 DP In, m - - DP Out/TD, m - 1,200 Round Trip DP Connections 0 78 DP Connection Time, hr 0.00 5.20 Csg In, m 300 300 Csg TD, m 1,200 1,200 No.of Csg Connections 73 73 Csg Connection Time, hr 6.08 6.08 Total Csg Running Time, hr 6.08 6.08 Csg Running+DP Conn. Time, hr 6.08 11.28 COUNTRY WELL NAME CUSTOMER HOLE SIZE DRILLING WITH CASING ECONOMIC ANALYSIS Ver.7.0 1. Well information 1 2 2. Casing & drill pipe connection time 3. DwC™ operation saving calculation 4 4. Breakeven ROP 5 5. Operation time © 2009 Weatherford. All rights reserved. 7 Time Depth Curve 100 300 500 700 900 1,100 1,300 1,500 0.0 0.5 1.0 1.5 2.0 2.5 Days Depth, ft Conventional DwC 30.0 30.0 0 10 20 DwC Drill & Run Csg Hours On Bottom Csg Running+DP Conn. Time, hr M/U and L/D BHA Prepare to Run Casing Reaming Circulate, Displ. Hi-Vis DS3 Conversion Other NPT 2 Other NPT 3 M/U and L/D BHA - 4.00 Prepare to Run Casing 1.00 1.00 Reaming 1.00 3.00 Circulate, Displ. Hi-Vis 1.00 1.00 DS3 Conversion 0.50 - Other NPT 2 - - Other NPT 3 - - Total Hrs 39.6 50.3 Total Days 1.6 2.1 ROP (incl. Connection), ft/hr 24.9 25.6 Rig Rate, USD/day $120,000 $120,000 Rig Rate, USD/hr $5,000 $5,000 Drlg Cost excl. DwC/Bit, USD $197,917 $251,417 Total DwC Cost, USD $48,292 $ - Bit Cost, USD - $25,000 Extra Savings, USD $ - $ - Drlg incl. DwC/Bit,USD $246,209 $276,417 Cost / m $274 $307 Saving $30,208 - 3 5. Operation time breakdown bar chart 6 6. Time-depth curve
- 9. Economic Analysis (Ver.7) CONNECTION TIME DwC Conv. Drillpipe Length / Std, m 12.2 30.5 Conn. Time / Std, min 5.00 4.00 Tripping Rate, m/hr 146 457 DP In, m - - DP Out/TD, m - 1,200 Round Trip DP Connections 0 78 Connection Time Calculation Drill pipe connection time © 2009 Weatherford. All rights reserved. 8 Round Trip DP Connections 0 78 DP Connection Time, hr 0.00 5.20 Csg In, m 300 300 Csg TD, m 1,200 1,200 No.of Csg Connections 73 73 Csg Connection Time, hr 6.08 6.08 Total Csg Running Time, hr 6.08 6.08 Csg Running+DP Conn. Time, hr 6.08 11.28 Casing connection time Total casing and drill pipe connection time
- 10. Economic Analysis (Ver.7) DwC VERSUS CONVENTIONAL DRILLING DwC Drill & Run Csg On Bottom ROP, m/hr 30.0 30.0 Total Drilled, m 900 900 Hours On Bottom 30.00 30.00 Csg Running+DP Conn. Time, hr 6.08 11.28 M/U and L/D BHA - 4.00 Prepare to Run Casing 1.00 1.00 Reaming 1.00 3.00 Circulate, Displ. Hi-Vis 1.00 1.00 Cost Saving Calculation On bottom time calculation Non productive time input Connection times from previous table © 2009 Weatherford. All rights reserved. 9 Circulate, Displ. Hi-Vis 1.00 1.00 DS3 Conversion 0.50 - Other NPT 2 - - Other NPT 3 - - Total Hrs 39.6 50.3 Total Days 1.6 2.1 ROP (incl. Connection), ft/hr 24.9 25.6 Rig Rate, USD/day $120,000 $120,000 Rig Rate, USD/hr $5,000 $5,000 Drlg Cost excl. DwC/Bit, USD $197,917 $251,417 Total DwC Cost, USD $48,292 $ - Bit Cost, USD - $25,000 Extra Savings, USD $ - $ - Drlg incl. DwC/Bit,USD $246,209 $276,417 Cost / m $274 $307 Saving $30,208 - Non productive time input Total operational time Cost analysis at given rig rate Final saving
- 11. Economic Analysis (Ver.8) COUNTRY INDONESIA SISI-NUBI CUSTOMER TOTAL INDONESIA 20" DATE 09-November-2006 Version 8 Procedure Conventional Hrs Cum. DayDeph (m) Drilling with Casing Hrs Cum. Day Deph (m) 1 R/U Casing equipment, M/U MLS hanger w/ landing assembly 2.00 0.08 188.73 R/U Casing equipment, M/U MLS hanger w/ landing assembly 2.00 0.08 188.73 2 R/D casing equipment 0.50 0.10 188.73 R/D casing equipment 0.50 0.10 188.73 3 M/U 26" BHA, RIH same to 48m 3.50 0.25 188.73 M/U 26" BHA, RIH same to 48m 3.50 0.25 188.73 4 Verification & Down load data MWD assy. 1.00 0.29 188.73 Verification & Down load data MWD assy. - 0.25 188.73 5 Continue M/U 26" BHA #2 and RIH same to 155m 1.50 0.35 188.73 Continue M/U 26" BHA #2 and RIH same to 155m 1.50 0.31 188.73 6 Test LWD and MWD assy. with 3500 LPM and 1800 psi, OK 0.50 0.38 188.73 Test LWD and MWD assy. with 3500 LPM and 1800 psi, OK - 0.31 188.73 7 Continue RIH 26" BHA #2 to 160m, washed down and tag TOC at 168m, drilled out cement, shoe and cleaned out rat hole. Pump sweep & circulate hole clean 5.00 0.58 188.73 Continue RIH 26" BHA #2 to 160m, washed down and tag TOC at 168m, drilled out cement, shoe and cleaned out rat hole. Pump sweep & circulate hole clean 5.00 0.52 188.73 8 - 0.58 188.73 POOH 1.50 0.58 188.73 9 Drilling 26" hole from 188.73 to 527m 15.00 1.21 527.00 Drilling 26" hole from 188.73 to 527m - 0.58 188.73 10 - 1.21 527.00 R/U casing equipment and DwC Spear 1.00 0.63 188.73 11 - 1.21 527.00 P/U shoe joint and RIH to 188.73m 2.50 0.73 188.73 12 - 1.21 527.00 Casing drilling 26" hole from 188.73 to 527m 18.00 1.48 527.00 13 Pump Hi-Vis 2.00 1.29 527.00 Pump Hi-Vis 2.00 1.56 527.00 14 Flow check 0.50 1.31 527.00 Flow check 0.50 1.58 527.00 15 - 1.31 527.00 L/D excess casings, space out 1.00 1.63 527.00 16 POOH from 527m, sweep hole, download MWD data, L/D BHA 10.00 1.73 527.00 POOH from 527m, sweep hole, download MWD data, L/D BHA - 1.63 527.00 PROJECT CASING SIZE DRILLING WITH CASING ECONOMIC ANALYSIS © 2009 Weatherford. All rights reserved. 10 16 POOH from 527m, sweep hole, download MWD data, L/D BHA 10.00 1.73 527.00 POOH from 527m, sweep hole, download MWD data, L/D BHA - 1.63 527.00 17 R/U casing equipment 0.50 1.75 527.00 R/U casing equipment - 1.63 527.00 18 P/U shoe joint, run casing to 424m 6.00 2.00 527.00 P/U shoe joint, run casing to 424m - 1.63 527.00 19 P/U and M/U MLS Hanger 1.00 2.04 527.00 P/U and M/U MLS Hanger 1.00 1.67 527.00 20 Cont. running casing to 519m 1.50 2.10 527.00 Cont. running casing to 519m - 1.67 527.00 21 Wash down fom 519m to 523m (shoe depth) and land the MLS Hanger assy. onto 30" Landing ring 1.50 2.17 527.00 Wash down fom 519m to 523m (shoe depth) and land the MLS Hanger assy. onto 30" Landing ring 1.50 1.73 527.00 22 Circulate hole clean 2.50 2.27 527.00 Circulate hole clean - 1.73 527.00 23 - 2.27 527.00 L/D DwC Spear 0.50 1.75 527.00 24 L/D circulating head, change long bails to drilling bails 0.50 2.29 527.00 Change long bails to drilling bails 0.25 1.76 527.00 25 RIH stinger with 17 std 1 single 5" DP to 505.61m 1.50 2.35 527.00 RIH stinger with 17 std 1 single 5" DP to 505.61m 1.50 1.82 527.00 26 M/U cement head, surface line and change to long bails 1.00 2.40 527.00 M/U cement head, surface line and change to long bails 1.00 1.86 527.00 27 Circulate hole clean with 150% volume 2.00 2.48 527.00 Circulate hole clean with 150% volume 2.00 1.95 527.00 28 Pump cement 2.50 2.58 527.00 Pump cement 2.50 2.05 527.00 29 Rig down cement head, POOH 5" DP 2.50 2.69 527.00 Rig down cement head, POOH 5" DP 2.50 2.16 527.00 Total Hrs Total Days % Time saving Rig Rate, USD/day Rig Rate, USD/hr DwC Cost, USD Bit Cost, USD Extra Savings, USD Total Drlg Cost, USD Cost / m Cost saving, USD % Cost saving $10,417 64.5 hrs 2.69 days $250,000 - 51.8 hrs 2.16 days $250,000 $10,417 $97,831 - n/a $25,000 n/a - 8.6% - 19.8% $0 $636,894 $1,883 $59,981 $696,875 $2,060 ..Forms and TemplatesDwC™ Economic Analysis ver8.xls
- 12. Economic Analysis (Ver.8) DwC vs Conventional Operations Comparison 15 0 5 5 0 0.5 1 .5 1.5 0 1 3.5 3.5 0.5 0.5 2 2 50 60 70 R/U Casing equipment, M/U MLS hanger w/ landing assembly R/D casing equipment M/U 26" BHA, RIH same to 48m Verification & Down load data MWD assy. Continue M/U 26" BHA #2 and RIH same to 155m Test LWD and MWD assy. with 3500 LPM and 1800 psi, OK Continue RIH 26" BHA #2 to 160m, washed down and tag TOC at 168m, drilled out cement, shoe and cleaned out rat hole. Pump sweep & circulate hole clean POOH Drilling 26" hole from 188.73 to 527m R/U casing equipment and DwC Spear P/U shoe joint and RIH to 188.73m Casing drilling 26" hole from 188.73 to 527m © 2009 Weatherford. All rights reserved. 11 2.5 2.5 2.5 2.5 2.0 2.0 1.0 1.0 1 .5 1.5 0.3 0.5 0 2.5 1 .5 1.5 0 1.5 1 1 0 6 0 0.5 0 10 0.5 0 1 0 0.5 0.5 2 2 1 8 0 2.5 0 1 0 0 1 .5 0 10 20 30 40 DwC Conventional HOURS Pump Hi-Vis Flow check L/D excess casings, space out L/D DwC Spear POOH from 527m, sweep hole, download MWD data, L/D BHA R/U casing equipment P/U shoe joint, run casing to 424m P/U and M/U MLS Hanger Cont. running casing to 519m Wash down fom 519m to 523m (shoe depth) and land the MLS Hanger assy. onto 30" Landing ring Circulate hole clean Change long bails to drilling bails RIH stinger with 17 std 1 single 5" DP to 505.61m M/U cement head, surface line and change to long bails Circulate hole clean with 150% volume Pump cement Rig down cement head, POOH 5" DP
- 13. Economic Analysis (Ver.8) Sisi-Nubi DwC vs Conventional Time Depth Curve 100 200 300 Conventional Drilling with Casing © 2009 Weatherford. All rights reserved. 12 400 500 600 0.0 0.5 1.0 1.5 2.0 2.5 3.0 Days Depth, m
- 14. Economic Analysis (Ver.8) CONNECTION TIME DwC Conventional Length / Std, m 12.2 30.5 Conn. Time / Std, min 10.00 4.00 Tripping Rate, m/hr 73 457 DP Out/TD, m - 527 Round Trip DP Connections 0 34 DP Connection Time, hr 0.00 2.27 Top Csg Depth, m 189 - Csg TD, m 527 527 IADC DRILLING TIME ESTIMATION © 2009 Weatherford. All rights reserved. 13 Csg TD, m 527 527 No.of Csg Connections 27 43 Csg Connection Time, hr 4.50 7.17 ON-BOTTOM TIME DwC Conventional On Bottom ROP, m/hr 26.0 26.0 Depth In, m KB 188.73 188.73 Total Drilled, m 338.27 338.27 Hours On Bottom 13.01 13.01 Predicted IADC Drilling Hours 17.51 15.28 No included in IADC Drilling Hour calculation
- 15. Drilling Hydraulics • The Borehole • Transports cuttings • Stabilizes the hole well and prevents cave-ins • Reduces the risk of formation fluids or gases flowing into the well • The Bit (Defyer™) © 2009 Weatherford. All rights reserved. 14 • The Bit (Defyer™) • Cleans the cuttings from the bit, preventing bit balling • Cools and lubricate the cutters • Other Drilling Equipment • Drives downhole motors and turbines • Provides a communications medium for MWD mud pulse telemetry.
- 16. DwC™ Hydraulics Program © 2009 Weatherford. All rights reserved. 15 Hydraulics Variables: 1. Flow Rate 2. Mud Weight 3. Total Flow Area (TFA) 4. Pressure Drop 5. Hydraulic Horsepower/Square Inch (HSI) 6. Jet Impact Force (JIF)
- 17. Marketing and Technical Information Resources Marketing and Technical Information Resources © 2009 Weatherford. All rights reserved. 16 Marketing and Technical Information Resources Marketing and Technical Information Resources
- 18. Weatherford Intranet © 2009 Weatherford. All rights reserved. 17