Design Process for Completions and Workovers Core COPYRIGHT. Design Process. This section will cover the following learning objectives:

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1 Learning Objectives Design Process for Completions and Workovers Core Design Process This section will cover the following learning objectives: Explain the work product of a completions engineer Describe an initial completion procedure and sketch Translate chronological steps from a procedure to a well sketch Recognize and describe morning reports Recognize the engineering that is required for developing a procedure 1

2 Work Product of a Completions Engineer The classic work product of a completion/ workover engineer Work Product of a Completions Engineer Pre-sketch Proposed sketch Procedure 1Engineering team develops the procedure 2

3 Work Product of a Completions Engineer 2 Operations team executes procedure in the field Work Product of a Completions Engineer 3 Work is documented through a series of morning reports 3

4 Work Product of a Completions Engineer Completions or work over engineer will review the 4 reports and discuss work status with operations team Work Product of a Completions Engineer Engineer uses morning reports to complete final 5 well sketch 4

5 Sketches and Procedures Initial Completion Pre-sketch Well left with 10 ppg mud in casing when drilling rig moved off location. 7 32#/ft casing run to 8000 with PBTD at 7850 Procedure 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Make bit and scraper run to PBTD 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid. Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10. Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. Sketches and Procedures Initial Completion Pre-sketch Well left with 10 ppg mud in casing when drilling rig moved off location. 7 32#/ft casing run to 8000 with PBTD at 7850 Proposed Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at Procedure Proposed Sketch 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 2 7/ Make bit and scraper run to PBTD 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL ppf API EUE completion fluid. N-80 tubing Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes The well in the current (original) condition. 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, SSD at 7390 For 2016) New with 4 5/8 Completion: gun loaded 6 spf, This 60 deg is phasing,32 generally gm RDX the way the Model MJG charges drilling rig left the well, so it is usually simple. Note packer set at 9. POOH with guns, check that all shots have fired, if not, inform that Engineering by tradition we do not show other casing strings nor Monitor the hole wellhead. conditions for But 4 hours, these report can any be fluid important, loss so do XN at 7405 not pressure forget build that up other casing stings exist in the well and 11. If well stable, TIH with completion string consisting of MS WL WEG at 7410 that reentry there guide, XN is something landing nipple, on model the MJG top. mechanical Perforations retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set For packer Workover: at This sketch may be very complicated, MD. Note, top 12. MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for with 15 min. lots RDMO of equipment SL. already in the well! sand at 7500, 13. Test backside to 5000 psi for 15 min. bottom sand at 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. 5

6 Sketches and Procedures Initial Completion Pre-sketch Well left with 10 ppg mud in casing when drilling rig moved off location. 7 32#/ft casing run to 8000 with PBTD at 7850 Procedure 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Make bit and scraper run to PBTD 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid. Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10. Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. Sketches and Procedures: Terminology MIRU move in and rig up SL slick line unit EL electric line RDMO rig down and move off PBTD plug back total depth TIH trip in hole; usually jointed pipe TOOH trip out of hole; usually jointed pipe RIH run in hole, often not pipe (e.g., wireline or coiled tubing) POOH pull out of hole ND nipple down (unfasten bolts; usually for a BOP or tree) NU nipple up Proposed Sketch 2 7/8 6.5 A series of chronologically ppf API EUE organized steps N-80 that tubing the operations team should follow to get to the proposed sketch. SSD at 7390 Model MJG Generally involves packer placing set at items into the well 7400 or pulling them out of the XN well, at 7405 and doing so in such a manner WEG at 7410 that the reservoir pressure is always contained Perforations no unwanted flow of reservoir MD. Note, top fluids to the surface! sand at 7500, bottom sand at MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Make bit and scraper run to PBTD 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid. Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10. Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. 6

7 Sketches and Procedures Pre-sketch Well left with 10 ppg mud in casing when drilling rig moved off location. 7 32#/ft casing run to 8000 with PBTD at MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO This is SLwhat the completion engineer wants to 4. If approval to proceed, MIRU completion rig get to the final state of the well. There is a lot 5. Make bit and scraper run to PBTD 6. TIH of engineering with open ended workstring, that goes displace into hole this with sketch; 9.8 ppg which KCL completion is the overall fluid. subject of this skill module. Note: expected reservoir pressure is 3600 psi at ppg fluid will Consider for now several questions: provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU Why EL unit, perforate hold explosives that safety interval? meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun Why just perforate, and not frac or gravel loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH pack? with guns, check that all shots have fired, if not, inform Engineering 10. Monitor Why hole run conditions that packer for 4 hours, and report that any fluid size loss tubing? or pressure build up Why run tubing at all? 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. Proposed Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at

8 Sketches and Procedures Intervention Pre Sketch Procedure Proposed Sketch 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. Note any sand or obstructions inside the tubing. 3. Make up lock mandrel with pressure gauges for XN landing nipple at Run lock mandrel and set in XN nipple, hang off gauges, pull running tool. 5. RDMO SL Sketches and Procedures Intervention Pre Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at Procedure 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. Note any sand or obstructions inside the tubing. 3. Make up lock mandrel with pressure gauges for XN landing nipple at Run lock mandrel and set in XN nipple, hang off gauges, pull running tool. 5. RDMO SL Proposed Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 Lock mandrel with pressure gauges hung off Feb WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at What is going to be done? 8

9 Sketches and Procedures Workover Pre Sketch 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Install BPV, remove tree, NU BOPs 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid. Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10. Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. Sketches and Procedures Workover Pre Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Install BPV, remove tree, NU BOPs 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid. Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10. Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. Proposed Sketch Proposed Sketch 2 3/8 4.7 ppf J-55 tubing SSD at 7390 Model XYZ packer set at 7150 XN at 7155 WEG at 7160 Perforations MD. Note, top sand at 7200, bottom sand at Cmt Retainer at 7400 Perfs squeezed with cement through cement retainer Perforations MD. 9

10 Morning Reports Final Post Well Sketch Morning Reports Morning Reports Morning Reports The work should go according to the procedure There may be slight or major differences There may be significant deviations The engineer will use the morning reports to develop a final post well sketch A report that the operations team prepares daily, usually in the morning (6 AM is a typical report time). These reports are industry standard. Globally, every company uses something similar. The format and content may vary slightly, but all contain similar information. What does your company use as a morning report tool? Reading these reports is important for most disciplines and managers involved in upstream activities. 10

11 Field Execution Equipment used in well completions and workovers: Rigs Coiled Tubing Units Snubbing, or Hydraulic Workover Units Electric Line Slick line Stand alone pumping operations (bull heading) See Well Intervention Core. Slick line Coiled tubing units Rigs Electric line Hydraulic workover unit 11

12 Sketches and Procedures Pre Sketch Well left with 10 ppg mud in casing when drilling rig moved off location. 7 32#/ft casing run to 8000 with PBTD at MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Make bit and scraper run to PBTD 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid. Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB. 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10. Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. Sketches and Procedures Pre Sketch 1. MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering. 3. This RDMO is SLthe proposed sketch. This is what the Well left 4. If approval to proceed, MIRU completion rig completion engineer wants to get to i.e., the with Make bit and scraper run to PBTD 6. final TIH with state open of ended the workstring, well. There displace is hole a lot with of 9.8 ppg KCL ppg mud engineering completion fluid. that goes into this sketch; which is in casing Note: expected reservoir pressure 3600 psi at ppg fluid will when the overall subject of this module. Consider for provide a 222 psi OB. drilling rig 7. now Test casing several to 5000 questions: psi for 15 minutes moved off 8. MIRU Why EL unit, perforate hold explosives that safety interval? meeting and conduct JSA. RIH and location. perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun Why run that packer and that size tubing? loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH Why with run guns, tubing check that at all all? shots have fired, if not, inform Engineering 10. Monitor Why hole just conditions perforate, 4 hours, and report not any frac fluid or loss gravel or pressure build up pack? 11. If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13. Test backside to 5000 psi for 15 min. 14. Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15. If required, use lease gas to rock well in, open on 16/64 ck. 7 32#/ft casing run to 8000 with PBTD at 7850 Proposed Sketch Proposed Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at /8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 WEG at 7410 Perforations MD. Note, top sand at 7500, bottom sand at

13 Engineering Design Components Completion Location Which zone? Multiple zones? Primary Sand Face Completion Method Do we need sand control or fracturing? Perforating Upper Completion Selection Tubing Selection Completion Fluid Barriers Almost always required how? What equipment is needed for safety and flexibility over the well s life Based on reservoir inflow over the life of the well, rate, pressure, fluid composition Needs to hold reservoir pressure and not damage (be compatible with) the reservoir Consider your barriers (usually two required) at each stage of the operation What Engineering Went into this Procedure? Completion location Which zone or zones? Where are our target zones of interest? Is there just one zone of interest or are there more? How are we going to approach this completion from the targets initially? Typically, some combination of open hole well logs and core data is used to help identify the zones and determine the relevant properties. 13

14 What Engineering Went into this Procedure? Primary Sand face completion method Lower Completion Just run casing and perforate (a satisfactory option if the reservoir is consolidated and has reasonable permeability) If the reservoir is unconsolidated, you may need to install some form of sand control If the reservoir has very low permeability, you may need to fracture the reservoir In most cases, we will need to select our perforation strategy as part of this sand face completion gun type, shots per foot, etc. See the Sand Control Core and Onshore Unconventional Well Completions Core modules for more information. What Engineering Went into this Procedure? Barriers General requirement to have two barriers in place for any operation A barrier is used in place for any uncontrolled loss of produced fluids leading to the environment Barriers change throughout completion/workover operations this is different from drilling operations where the two barriers (mud and the BOPs) are fairly constant Tubing Packer Tubing and Packer Sub surface safety valve Christmas tree 14

15 What Engineering Went into this Procedure? Barrier Upper completion selection Includes: Selection of the flowing conduit (usually up through tubing with a packer installed, but not always) Type of packer Selection of other equipment (in this example the wireline reentry guide, the XN landing nipple, and the sliding side door), and might include others, including subsurface safety valves. The selection of those components will be based on a range of factors including safety and long term flexibility Must select tubing size, grade, and connections Requires analysis of Darcy s Law Also look at pressures and the long term drive mechanism to determine the optimum tubing What Engineering Went into this Procedure? Barrier Select the metals and elastomers Based on fluid components, pressure, and temperature Select the completion fluid Always a clear brine, NOT drilling mud Multiple factors: Completion fluid must have sufficient hydrostatic head from the density to control the reservoir pressure at reservoir depth Completion fluid must be able to control the reservoir pressure while in the completion phase Completion fluid must also be compatible with the formation, both the rock and the reservoir fluids. Barrier Selection of components Selection of completion fluid 15

16 What Engineering Went into this Procedure? If your well is capable of flowing naturally at pressure, then a tree will need to be selected. Select a tree based on pressure, and any corrosive fluids you may have. 16

17 Learning Objectives This section has covered the following learning objectives: Explain the work product of a completions engineer Describe an initial completion procedure and sketch Translate chronological steps from a procedure to a well sketch Recognize and describe morning reports Recognize the engineering that is required for developing a procedure 17

18 Back to Work Suggestions Design Process for Completions and Workovers Core Leverage the skills you ve learned by discussing the skill module objectives with your supervisor to develop a personalized plan to implement on the job. Some suggestions are provided. Find and review a completion procedure that has been done in the field. Find the procedure, the pre-sketch, the proposed sketch, the final sketch and the morning reports. Review these documents, and discuss your review with a senior completions engineer. 18

19 Learning Objectives Design Process for Completions and Workovers Core Basis of Design This section will cover the following learning objectives: Explain and provide an example of Basis of Design (BOD) Compare and contrast design and BOD 19

20 Cooking Analogy Introduce the Basis of Design List of ingredients Process Planned outcome Recipe You may want to pause PAUSE a moment to review Basil chicken recipe Marinate chicken for 4 hours in a blend of balsamic vinegar, juice of 2 lemons including the lemon pieces, olive oil, fresh rosemary, garlic, salt, pepper Prepare basmati rice with sliced mushrooms Prepare sautéed broccoli, olives, red bell peppers, and green beans, add drizzle of soy sauce and splash of sherry Prepare salad of lettuce, fresh tomatoes, feta cheese, and salad dressing of choice Cook chicken in cast iron skillet, with lemon pieces, turning frequently until done, season with garlic, salt, pepper Place cast iron skillet with chicken in oven on warm with whole fresh basil leaves on top Lightly wilt spinach in some of the juices from the cast iron skillet Serve chicken on the wilted spinach, basil on top, with rice, vegetables, and salad Cooking Analogy Introduce the Basis of Design A lot of thinking before cooking Cultural preference? Taste preference? Health? Chicken on sale that day? Taste? Had pork the day before? Equipment? 20

21 Basis of Design What is a Basis of Design (BOD)? Design vs. Basis of Design What (Design) 1. Run 3.5 tubing 2. Run 13 chrome tubing 3. Perforate at Use Service Company X for all equipment 5. Install sand monitoring on flow line The BOD is the why to the program s what BOD is all the things you (should) consider when developing the proposed sketch and the procedure/ equipment selection Many of these things you considered have significant uncertainty at the Completion stage since this occurs at the beginning of the well life BOD is critical to document Why (Basis of Design) 1. Reservoir properties indicate inflow is best handled by Reservoir fluid analysis shows CO 2 3. Interpreted Petrophysical logs indicate the best pay , but the reservoir drive is expected to be water influx 4. Procurement has a sole source contract with X 5. Geologic work suggests potential for unconsolidated sandstone 21

22 Example BoD for our Example Well Pre Sketch Well left with 10 ppg mud in casing when drilling rig moved off location 7 32#/ft casing run to 8000 with PBTD at MIRU SL 2. Hold safety meeting. Make gauge ring run to PBTD est. 7850, send results to Engineering 3. RDMO SL 4. If approval to proceed, MIRU completion rig 5. Make bit and scraper run to PBTD 6. TIH with open ended workstring, displace hole with 9.8 ppg KCL completion fluid * Note: expected reservoir pressure is 3600 psi at ppg fluid will provide a 222 psi OB 7. Test casing to 5000 psi for 15 minutes 8. MIRU EL unit, hold explosives safety meeting and conduct JSA. RIH and perforate (reference OH log dated Nov 9, 2016) with 4 5/8 gun loaded 6 spf, 60 deg phasing,32 gm RDX charges 9. POOH with guns, check that all shots have fired, if not, inform Engineering 10.Monitor hole conditions for 4 hours, report any fluid loss or pressure build up 11.If well stable, TIH with completion string consisting of MS WL reentry guide, XN landing nipple, model MJG mechanical retrievable packer, sliding side door, and 2 7/8 6.5 #/ft tubing. Set packer at MIRU SL, set plug in lower XN nipple, test tubing to 5000 psi for 15 min. RDMO SL. 13.Test backside to 5000 psi for 15 min. 14.Install BPV, ND BOPs, NU 5000 psi tree and flowlines, pull BPV, turn well over to Production 15.If required, use lease gas to rock well in, open on 16/64 ck. You may want to PAUSE pause to review the information. Proposed Sketch 2 7/8 6.5 ppf API EUE N-80 tubing SSD at 7390 Model MJG packer set at 7400 XN at 7405 Lock mandrel with pressure gauges hung off Feb WEG at 7410 Perforations MD. Note: top sand at 7500, bottom sand at 7610 a moment 22

23 Back to Work Suggestions Design Process for Completions and Workovers Core Basis of Design Leverage the skills you ve learned by discussing the skill module objectives with your supervisor to develop a personalized plan to implement on the job. Some suggestions are provided. Find and review a Basis of Design statement used in your company for a recent completion. Discuss your review with a senior completions engineer. Note, not all companies have these titled documents, if not, talk with a senior completions engineer about how the elements within a typical BoD are incorporated into your company s work process. 23

24 Learning Objectives This section has covered the following learning objective: Explain and provide and example of Basis of Design (BOD) Compare and contrast design and BOD 24

25 Back to Work Suggestions Design Process for Completions and Workovers Core Basis of Design Leverage the skills you ve learned by discussing the skill module objectives with your supervisor to develop a personalized plan to implement on the job. Some suggestions are provided. Find and review an AFE, AAR, and CWOP. Discuss your review with a senior completions engineer. Note, not all companies use all three of these products. You should be able to find an AFE, as these are very standard. If you do not find an AAR or CWOP, discuss the reasons why your company does not use them in your work process who knows, maybe there is an opportunity for improvement! 25

26 Learning Objectives Design Process for Workover and Completions Core Linkage to Management Systems This section will cover the following learning objective: Illustrate and explain the link between management systems and the engineering design process 26

27 Linkage to Management Systems This is usually represented as a wheel and comes from the work of Deming. Project Management Business Management Safety Management Quality Management Linkage to Management Systems PLAN DO CHECK ACT Basis of Design, Proposed Sketch, and CWOP matches up with the procedure Operations follows the procedure Daily morning reports are reviewed by the Operations and Engineering team Immediate corrections may be made to the well completion based on new data The AAR, morning reports, and the post sketch all feed into the next PLAN (a revised Basis of Design and Proposed Sketch). Many companies actively follow a Project Management approach to well drilling and completions. Several major service companies have divisions that offer fully integrated drilling and completion package divisions, total packages, and these typically are built around the project management methodology. 27

28 Learning Objectives This section has covered the following learning objective: Illustrate and explain the link between management systems and the engineering design process 28

29 Learning Objectives Design Process for Completions and Workovers Core Completion Design This section will cover the following learning objective: Identify the objectives of a completion Identify and describe each aspect that is to be considered to achieve the two objectives Compare the different drive mechanisms 29

30 Drive Mechanisms Generally, three main types of drive mechanisms are considered active in the Petroleum Industry. For Oil Reservoirs Solution Gas Drive Gas Cap Drive Water Drive Depletion or Gas Expansion Water Drive Solution Gas Drive For Gas Reservoirs There may be a combination of more than one type, and they may have different contributions to the overall drive of the reservoir weak vs. strong water drive, for example Solution gas drive The gas dissolved in oil comes out of oil and expands pushing the oil out of the reservoir Oil Zone Liberated Gas 30

31 Solution Gas Drive Performance P i RESERVOIR PRESSURE RESERVOIR PRESSURE PRODUCING GAS-OIL RATIO DAILY OIL PRODUCTION RATE R si P b DAILY OIL PRODUCTION RATE TIME Idealized typical solution gas drive performance behavior. Gas Cap Drive Reservoir Gas cap drive PRODUCING GAS-OIL RATIO The free gas in the reservoir expands and pushes the hydrocarbons out Original GOC Liberated Gas 31

32 Gas Cap Drive Performance P i RESERVOIR PRESSURE RESERVOIR PRESSURE PRODUCING GAS-OIL RATIO DAILY OIL PRODUCTION RATE P b R si DAILY OIL PRODUCTION RATE TIME Idealized, typical gas cap drive performance behavior. Water Drive Reservoir PRODUCING GAS-OIL RATIO Water (aquifer) drive The underlying aquifer pushes the hydrocarbons to the surface Oil Zone Water-Invaded Zone Original WOC Water 32

33 Strong Water Drive Performance P i RESERVOIR PRESSURE RESERVOIR PRESSURE PRODUCING GAS-OIL RATIO DAILY OIL PRODUCTION RATE DAILY WATER PRODUCTION RATE R si P b TIME Idealized, typical strong water drive performance behavior. PRODUCING GAS-OIL RATIO DAILY OIL PRODUCTION RATE DAILY WATER PRODUCTION RATE 33

34 The Petrophysical Scene Formation Evaluation While Drilling Wireline Reservoir Monitoring Mudlog data Core data Open hole logs: Resistivity Nuclear Acoustic Other Corrections: - invasion - layering - deviation Interpretation models incl. QC and Uncertainty Cased hole logs: Nuclear Production logs Other 34

35 Completion/ Workover Design Program Design and Selection Equipment Design and Selection Sandface Completion Sand Control Frac Acid Perforating Method Completion Fluid See Design Fundamentals for more information the design phase. Ancillary Equip. 1. Flexibility Wireline nipples Circulating devices Chemical injection mandrels Artificial lift 2. Durability Flow couplings Tubing seals Blast joints Sand Control Equip Essential Equip. Tubing/ connection Wellhead/ tree Subsurface safety systems Packer 35

36 Learning Objectives This section has covered the following learning objectives: Identify the objectives of a completion Identify and describe each aspect that is to be considered to achieve the two objectives Compare the different drive mechanisms PetroAcademy TM Completions and Workovers Onshore Conventional Well Completion Core Design Process for Completions and Workovers Core Perforating Core Onshore Unconventional Well Completion Core Sand Control Core Hydraulic Fracturing Design Fundamentals Well Completion Fundamentals Formation Damage and Matrix Stimulation Core Flow Assurance and Production Chemistry Core Production Problem Diagnosis Core Well Intervention Core Workover Fundamentals 36