Drilling Operations Summary

The RIG will be mobilized from XXX to XXX. The rig will be moored in approximately xxx’ water depth. A string of 36” x 1.5” and 1.0" wall structure pipe will be jetted to xxx’ TVD / MD (xxx’ BML). The shallow hazards survey indicates possible low risk shallow gas potential from the mudline to approx. xxx’ TVD (xxx’ BML) and negligible to moderate risk shallow water flow potential at xxx’ TVD / MD (xxx’ BML).

After jetting the 36” structure pipe to the desired depth, the Drill Ahead Tool (DAT) will be used to drill 26” hole to xxx’ TVD / MD (xxx’ BML) and 20” casing will be run and cemented. The shallow water flow study indicates only low to moderate potential for over-pressured sands through this interval. Should a shallow flow be encountered while drilling riserless, 16.0 ppg kill mud will be available on the rig to control any such flow. After running and cementing 20” casing, the subsea BOP stack and riser will be run and tested. Prior to drilling out of the 20” casing, the hole will be displaced with 10.0 ppg synthetic based mud. A LOT of 10.7 ppg is expected at the 20” casing shoe. LWD (GR/RES/APWD/DIR) will be utilized in this hole section.

A 17’’ x 20” hole will be drilled to xxx’ TVD / MD and 16” casing will be run and cemented. This casing string is being set at this depth based on pore pressure and frac gradient. The expected mud weight at casing point is 10.4 ppg and the expected LOT at the 16” casing shoe is 12.4 ppg EMW. LWD (GR/RES/APWD/DIR) will be utilized in this hole section.

A 14 1/2’’ x 17 1/2” hole will be drilled to xxx’ TVD / xxx’ MD. The KOP for the directional work is planned at 7300' TVD/MD. A major azimuth change while building hole angle will be accomplished in this section using rotary steerable tools. A full string of 13 5/8” casing will be set. The expected mud weight at casing point is 12.0 ppg and the expected LOT at the 13 5/8” casing shoe is 14.2 ppg EMW. LWD (GR/RES/APWD/DIR) will be utilized in this hole section.

A 12 1/4’’ x 15" directional hole will then be drilled utilizing rotary steerable tools and LWD (GR/RES/APWD/DEN/NEUT/DIR) to xxx' TVD / xxx' MD. The 1st target zone will be encountered in this hole section at xxx' TVD. A wireline logging program consisting of GR/Dipole Sonic, RCI, and SWC will be run in this hole section. An 9 7/8" liner will be set in this hole section. The expected mud weight at casing point is 13.0 ppg and the expected LOT at the 11 7/8” casing shoe is 14.9 ppg EMW.
A 9 7/8’’ x 12 1/4" directional hole will then be drilled utilizing rotary steerable tools and LWD (GR/RES/APWD/DEN/NEUT/DIR) to xxx' TVD / xxx' MD. The primary target zones will be encountered in this hole section at xxx' TVD and xxx' TVD. A wireline logging program consisting of GR/Dipole Sonic, RCI, and SWC will be run in this hole section. A 9 7/8" liner will be set in this hole section. The expected mud weight at casing point is 14.4 ppg and the expected LOT at the 9 7/8” casing shoe is 15.8 ppg EMW.

An 8-1/2’’ hole will then be drilled to TD at xxx’ TVD / xxx’ MD utilizing rotary steerable tools and LWD (GR/RES/APWD/DEN/NEUT/DIR). The lower target zones will be encountered in this hole section at 14110' TVD and 14506' TVD. A wireline logging program consisting of GR/Dipole Sonic, RCI, SWC, MRILL, Earth Imager, and Check Shot will be run in this hole section. The expected mud weight at TD is
ppg. No casing will be set in this hole section.

Based on the formation evaluation results, either this hole section will be permanently abandoned and the cased hole temporarily abandon pending completion, or the entire well will be permanently abandoned.

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Pre-Spud Activities

Pre-Spud Meetings

DWOP exercises will be conducted with drilling contractor personnel, service company personnel, COMPANY drilling supervisors and engineering staff prior to spud.

Prior to Mobilization

Before mobilizing, the following should be accomplished:

• Ensure mud pits and bulk tanks are cleaned from previous job.
• Back load rig with spud gear (i.e. 36’’ & 20’’ casing) and all related tools and equipment.
• Mud pits and sand traps should be empty for transit.
• ~xxx’ riser on deck and inspected
• Top off rig with fuel, water, and cement for 20’’ casing (DeepCRETE blend).
• Inspect rig’s 9 1/2’’ & 8’’ DC (9 jts each)
• Utilize derrick capacity – Rack back 6 5/8’’ HWDP and 5 1/2" Landing string as VDL allows
• 3rd Party personnel to inspect their equipment

Rig Mobilization and Move Onto Location

• The rig will be mobilized from XXX. The move is anticipated to take 8 hours. When rig reaches XXX, the rig will approach the location from the North. (Refer to FUGRO site survey for information on bottom conditions, hazards, etc.).
• The rig will go on hire for XXX when it is under tight tow from XXX.
• As the rig approaches the actual location, the AHV will begin placement of the 1st anchor. XXX will provide tools, equipment, crews for anchor handling operations, and contingency equipment.
• While holding rig on station, the remaining anchors will be run per the mooring procedure and the placement confirmed by the surveyors on board. Once on location AHV will begin running anchors as per mooring procedures. Once the 4 primary anchors are run and pretension, the tug can be released.
• Pretension anchor chains to Contractor’s specifications for the rig. The rig will then ballast to drilling draft, and storm tension the mooring system.
• Check rig positioning system with surveyor’s system to verify accuracy.

NOTE: Any deviation from the new SHL must be kept within the APD allowance and discussed with the Houston office.

• Load well tangibles and materials as necessary. Rig up communications.

Start-up Equipment, Materials and Personnel

The COMPANY Drilling Supervisors, Logistics Coordinator and Drilling Superintendent will prepare an initial “Required Personnel and Equipment” load-out list.

Ensure the following information and documentation is on board the rig:

• Signed copy of drilling program
• Approved copy of the MMS Application for Permit to Drill
• Guidelines - Subpart ‘O’
• Mud Program
• Cementing Program
• Subsea Wellhead Manual
• Evacuation Plan and Emergency Response Plan (Oil Spill Plan)
• IADC Deepwater Well Control Guidelines
• Emergency Evacuation Plan & Letter from Coast Guard confirming receipt

Pre-Spud Operations

• Rig should inspect and change where necessary valves in active pits.
• RU the Flow Process Technologies Blender eqpt. for operations in 26’’ hole interval.
• Have Vetco’s wellhead eqpt. and running tools visually inspected
• Inspect the BOP stack and change necessary rubbers. BOP ram stack up from bottom is Blind/Shear - 3 1/2" x 7 5/8" VBR - 3 1/2" x 7 5/8" VBR - 3 1/2" x 7 5/8" VBR.
• Stump test the BOP stack to 10 M psi (70% for the annular preventers) per APD Variance. Test surface equipment to 10 M.
• Measure and inspect the 36” casing. Clean the 36” casing connectors (RL-4 RB). Vetco representative should inspect the connections for damage. Apply light oil to box and pin surfaces and re-install pin protectors.
• Rig up and inspect all 3rd party equipment – centrifuge, augers, cuttings dryer, mud logging equipment & sensors, MWD/LWD equipment as necessary.

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36" Jet String

xxx' - xxx' TVD RKB (ML to +/-xxx' BML)

36" Casing, Wellhead Housing and Jetting Assembly

Hold pre-job safety meeting on running casing with all parties involved.

Verify 36" casing and jetting assembly tallies to ensure bit is no more than 6-8" outside the casing shoe. Adjust BHA length by the use of drill pipe pup joints and/or by cutting the 36" beveled end to fit.

DO NOT FORGET TO INCLUDE THE WELLHEAD HOUSING AND EXTENSION TO THE CASING TALLY

P/U and stand back drill pipe and inner jetting assembly with a rock 26" bit. P/U CADA (Cam-Actuated Drill Ahead) running tool, M/U on wellhead housing and stand back.

Jetting BHA

• 26" Bit - 12 3/4" Mud motor - 25 7/8" STB - 9 1/2" MWD/LWD - NM Screen Sub
• 25 7/8" NM STB - PBL Sub - 1 x 9 1/2" NMDC - 2 x 9 1/2" DC - XO - 2 x 8" DC
• 1 x 8" Short DC - Vetco CADA Tool (BWH) - Vetco CADA Tool (AWH) - XO
•  9 x 6 5/8" HWDP - 6 1/2" Hydraulic Jars - 8 x 6 5/8" HWDP - 5 1/2" DP

Paint stripes on the casing every 10'. Paint stripes every 2' for the 10' immediately below the wellhead housing.

Hold safety meeting to discuss running of 36" casing string.

Position gas/mud mat in the moon pool.

R/U to run 36” jet string.

P/U joint with beveled end x Vetco RL-4RB pin and run through rotary. Clean threads and apply AP-5 grease or lead-free API modified casing dope. Do not use any use API or other metallic- base thread compound.

Run required joints to allow 280' of penetration BML with 12' of stick up with the gas/mud mat at the ML. Make up connection and torque to recommended optimum torque. (See detailed VETCO procedure in the specific casing program section) Clean threads and apply API modified casing dope.

36" Casing String

• 1 Jt. 36" x 1" WT Beveled End x Vetco RL-4RB Pin
• Approx. 4 Jts. 36" x 1" WT Vetco RL-4RB Box x Vetco RL-4RB Pin
• 1 Jt. 36" x 1 1/2" WT Vetco RL-4RB Box x Vetco RL-4RB Pin
• 1 Jt. 36" x 1 1/2" WT Vetco RL-4RB Box x Vetco RL-4RB Housing Extension
• Vetco 36" MS-700 Wellhead Housing

Note: Housing Extension is one of the 2 required joints of 1 1/2" WT pipe.

 P/U 36" low pressure housing with extension and make up on top joint of 36".

Land the wellhead in a false rotary on the spider beams.

Disengage the CADA and stand back.

Run the inner jetting assembly.

Make up CADA on inner jetting assembly and land in wellhead housing. Confirm the tool is locked in the housing and the ports in the top of the tool are open.

Paint a vertical stripe across the tool and housing to verify proper rotation subsea.

MU bull’s-eye and bracket on the housing and record the angle and direction.

Install the gas/mud mat as follows:

• Position the split gas/mud mat on the moon pool beams / support structure without damaging the neoprene sheet seals.
• Pull the two halves back to either side of the moon pool area so that they are positioned for sliding together. Secure the two halves with chains or tack weld to the deck.
• Lift the wellhead in order to level welded support collar on the extension with the moon pool beams.
• Pull the two gas/mud mat halves together with cables/pulleys using the two threaded studs through mating holes to guide the halves together.
• Check neoprene sheet seals just prior to closing the gas mat halves.
• Make up the cap screws/studs to clinch the two halves together and compress the neoprene sheet seals.
• Apply silicon caulking compound above the neoprene sheet seals as a secondary seal mechanism.

Jetting 36"

Hold pre-job safety meeting on jetting procedures with all parties involved.

Pick up the entire structural casing string and wellhead assembly and note the weight. Lower the casing assembly on the landing string until the shoe is located 10' above the mud line as follows:

• Lock the rotary, TDS and blocks to ensure no rotation of the drill string.
• Monitor casing running operations with the ROV.
• Ensure drill pipe is filled every five stands.
• Verify rig location and adjust rig position as casing is run.
• At 15' above mud line record bull’s-eye angle and direction and record casing/jetting assembly weight.

Slowly lower the casing shoe to the mud line on the compensator.

• Continuously monitor the spud, mud returns at the seafloor, casing, and bull’s-eye with the ROV.
• Start pump at 200 gpm to keep bit nozzles from plugging when tagging mud line. Record string weight. Tag mud line and record depth. Record bull’s-eye angle and direction.
• Lower casing until it takes weight to determine the competent mud line. Record this depth as the competent mud line depth.
• Slowly increase WOB to 10-15 kips and flow rate to 400-700 gpm. Use minimum WOB for first joint to keep casing orientation vertical.
• Verify running string remains straight and casing is vertical as running string is lowered.

Jet casing

Seawater with Hi-vis Gel Sweeps

Fluid Type:                MW         PV          YP           MBT                        LGS
Seawater                  8.6
Hi-vis Gel Sweeps -   8.8-9.0    8-12        20-30       22.5 - 27.0 ppb      <6%

• Flow rate: increase to an optimum 1400 gpm (keep returns density as low as possible).
• WOB: below maximum set down weight limit for 36" (see Figure at end of this jetting procedure).
• ROP: limit in order to prevent plugging casing/jetting string annulus resulting in flow around the casing.
• Pump 50 bbl (slugging pit volume) gel sweeps prior to each connection (more frequently, as needed).
• Reciprocate casing as required (30' - 40' stroke length recommended) to prevent packoffs inside casing, to reduce friction between the structural casing and jetted formation, and maintain jetting progress once resistance / soil friction begins increasing (recommend to be reciprocating by 100' BML at LATEST). Successful operations have reciprocated as often as every other 5' to avoid formation creep from sticking structural casing. Reciprocation and sweeps are key elements to a successful jetting operation. Past experience indicates that jetting to xxx'' to xxx' BML provides sufficient skin friction to support wellhead loads.

NOTE: If required to adequately work the pipe, deactivate the compensator.

• Record bull’s-eye reading on each connection. Maintain deviation below 1.0°.
• Last 30':
  • Monitor gas/mud mat with ROV. Place gas/mud mat at the visible mud line.
  • Attempt to place the last 15' with the maximum allowable weight to improve structural integrity.
• At TD: Circulate hi-vis pill around. Record final setting depth and bull’s-eye readings.
• Record the following data on a basis: Time to jet 5', WOB, gpm, psi, comments, and notations on pipe reciprocation (when and how much the pipe was reciprocated) and the pumping of sweeps (volume and viscosity). Also note any overpull while working pipe.

Hold the casing in place at least 4 hours while soil friction increases around casing. Check bull’s- eye level of the wellhead with the ROV periodically.

Slack off weight and ensure casing is stable and remains straight. Record final bull's eye level. Notify Drilling Superintendent if it is greater than 1.0o.

Release Vetco CADA and continue drilling next hole section as per this program. Upon pulling out of the hole, CADA will be lifted by the inner string without a special operation.

figure x (to be included)

Predicted vs Actual 36" Casing Jetting Setdown Weight

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26" Hole and 20" Casing

xxx' - xxx' TVD RKB (xxx' – xxx' BML)

Drilling 26" Hole

Drill ahead to TD with seawater

Hole Section Mud Properties:

Seawater with Hi-vis Gel Sweeps

Fluid Type:                MW         PV          YP           MBT                        LGS
Seawater                  8.6
Hi-vis Gel Sweeps -   8.8-9.0    8-12        20-30       22.5 - 27.0 ppb      <6%

• Use 6½" mud pump liners.
• Flow rate: 1400 gpm (use lower rate while commencing drilling below 36" shoe to avoid washout).
• WOB: maximum 10 - 20K (avoid plugging annulus, building angle, and buckling drillstring).
• RPM: 90 - 150 for rotary
• ROP: limit to < 100 ft/hr as hole conditions allow.
• Have sufficient volume of 16 ppg KWM on hand, at least 2000 bbls.
• Pump 50 bbl (or slugging pit volume) hi-vis (FV > 100 sec) sweeps of seawater and prehydrated bentonite at each connection (more frequently if needed) and 50 bbl (or slugging pit volume) hi-vis pill at each half stand drilled.
• Take MWD directional survey readings every stand.
• Make wiper trips prior to interval TD only if required by hole conditions.
• Monitor wellhead for returns or well flow with ROV. Monitor drillpipe above wellhead for buckling.
• Drill hole to fit casing tally with 20' - 25' of rat hole below casing shoe. Do not drill more than 50' beyond APD shoe depth, 5278' TVD/MD RKB.

At TD pump 150 bbl hi-vis (FV>150) sweep. Dilute 16.0 ppg KWM to make 13.5 ppg pad mud.

Make a wiper trip to the structural casing shoe with seawater in the hole. Circulate hole clean and displace 150% hole volume with 13.5 ppg CaCl2 spotting mud. To prevent potential wellbore instability, DO NOT place freshwater mud in the hole.

POOH SLM: (DO NOT pump out after displacing hole to viscous mud)

• Wash the wellhead with the bit while pulling out of hole.
• Monitor the wellhead for flow until after bit is out of the hole.
• Ensure MWD survey and bulls-eye indicates a wellbore angle of 1.0o or less. If 1.0o angle is exceeded, check the rig offset and consult with the Drilling Superintendent.

Encountering Shallow Gas

• Conduct pre-spud meetings to remind personnel of hazards and contingency responsibilities.
• Perform flow checks with ROV when making connections.
• If a gas flow is encountered, start or continue pumping mud at maximum rate and sound alarm to alert all personnel.
• Post personnel to monitor water surface for gas bubbles and prepare to move rig into the current if gas bubble is present and in close proximity to the rig.
• Utilize the blender to increase the mud weight from 12.0 to 14.0 ppg and circulate a minimum of two hole volumes. Circulate at max. rate during kill. Monitor ECD with the APWD readout.
• Shut down pumping and monitor well for flow with ROV. If well is still flowing, continue mud weight increase to kill the flow. Once well is dead, options will be discussed with members of the extended drilling team.

Encountering Shallow Water Flows

• If a water flow is encountered, attempt to determine relative severity of flow. If water flow is minimal, consideration will be made to continue drilling to the 20” casing point. If flow is severe, increasing the mud weight or a dynamic kill will be considered. In either case, contact the COMPANY drilling staff to discuss options.
• Be sure well is dead prior to tripping.

In the event of encountering either shallow gas or shallow water flow, the cement loaded for the 20" casing is acceptable for and will be used for the 26" contingency.

Hole Cleaning / Lost Circulation

Lost circulation could occur if high annular loading results in an EMW greater than fracture gradient. Monitor APWD to determine ECD. Control drill this section at <100 ft/hr using as high of flow rates as practicable. Close observation to return flow via ROV is the only way to qualitatively tell if partial or full losses happen to occur.

Short trips may be made, if necessary, to evaluate hole condition and to minimize the potential for stuck pipe.

If hole conditions deteriorate, torque increases, or if fill is observed either on connections or a short trip, it may be necessary to increase the volume, frequency, and viscosity of the hole cleaning sweeps.

Running 20" Casing (20" x 0.812" WT 169 PPF N-80 Big Omega IS MS)

Out of critical path: Paint the float shoe yellow and paint yellow stripes every 5' on shoe joint.

Winch the rig to the safe zone while picking up 20" casing and inner string.

Hold pre-job safety meeting on running casing with all parties involved.

Make up WHRT to 20" WH joint (with nominal seat protector and sufficient inner cement stinger to protrude from WH extension joint). Lay out on pipe rack or catwalk.

DO NOT FORGET TO INCLUDE THE WELLHEAD HOUSING AND EXTENSION TO THE CASING TALLY.

 NOTE: Make sure VETCO serviceman uses a VX protector on the wellhead in order to protect the metal-to-metal sealing area of the wellhead. Also check to make sure a VETCO VT/VX gasket is available on the rig should the VX sealing area become damaged.

The 18 3/4" WHRT should be made up with DOUBLE ball valves installed on the vents.

Make up ATC Top Drive Single Plug Cementing head and stand back.

Prepare to run casing.

1. Bottom 4 casing joints will have a total of 6 centralizers across double stop collars (2 ea. on the 2 shoe jts. and 1/jt on next 2 jts.).
2. Paint a contrasting vertical stripe on the running tool stem and WH housing to verify proper tool rotation subsea.
3. Rig up the handling equipment for running the 20" casing.

Make up 20" casing. When making up Big Omega IS MS type connections, MU Torque should be 20000 ft-lbs.

20" Casing String

• Float Shoe bucked onto 1 Jt. 20" 169# N-80 Big Omega IS MS Pin x Big Omega IS MS Box
• Approx. 12 Jts. 20" 169# N-80 Big Omega IS MS Pin x Big Omega IS MS Box - Vetco 16" Landing Collar
• Approx. 34 Jts. 20" 169# N-80 Big Omega IS MS Pin x Big Omega IS MS Box
• 1 Jt. 20" x .812" WT Big Omega IS MS Pin x Big Omega IS MS Box Housing Extension
• Vetco 18 3/4" MS-700 Wellhead Housing

Note: Extension may be a full joint of 20" casing.

1. Apply torque with manual tongs.
2. Float shoe to welded onto 1st joint of casing.
3. Install 2 centralizers with 1 stop collar for each centralizer on each of the bottom 3 joints. Install 1 centralizer with 1 stop collar at mid-joint on each of the next 3 joints. A total of 9 centralizers are to be run.
4. Fill casing as it is run with seawater.

Collapse Caution: It is imperative that the casing string and drill pipe running string be full of fluid while running. Once the 20” shoe has entered the 36” Low Pressure Wellhead Housing, pump at least 1-1/2 casing volumes to assure that the strings are full.

Before making up WH joint, install a key-slot plate, bowl, and slips on top of the 20" casing. Pick up the 5 1/2" 21.90 ppf DP inner cementing string.

1. Drift inner cementing string as run using 2 5/8" drift.
2. PU ATC dart catcher Sub and Down Jet Sub and run on inner string.
3. Position the end of the inner cementing string ±60' above the float shoe.
4. Pick up WH / WHRT assembly. Make up inner cementing string to WHRT. Remove key slot plate.
5. Ensure WHRT vents are open for pumping air out of 20" x inner cementing string annulus.

Pick up the 5 1/2" 38 ppf landing string and RIH. Lower the wellhead to the water and pump out all the air from the 20" x inner string annulus. Close the both vent valves on top of the running tool (vent valves should have double valves for redundancy).

Continue running the casing on drill pipe to the mud line, filling the drill pipe every 5 stands. See Figure No. 2 at the end of this section for running weights and tensile capacities.

Winch rig from safe zone to location over the wellhead for stabbing 20" casing.

Activate the motion compensator. Use ROV to help stab 20" conductor into WH housing.

Continue running casing.

1. Wash with weighted mud if needed due to hole conditions. Do not "routinely" wash casing to bottom (avoid displacing the 13.5 ppg mud whenever possible).
2. Pump hi-vis gel sweeps as needed in tight spots. Switch to 13.5 ppg mud sweeps if necessary.
3. Monitor 20" movement at the WH with the ROV. Ensure drill pipe movement at the rig floor is consistent with casing movement at the wellhead to avoid buckling the 20" casing.
4. Trip in at ±1min/std to prevent lost returns once the 20" shoe enters WH housing.

Land and latch the HPWH into the LPWH housing while observing with the ROV.

1. Pull 30 kips overpull to verify the latch.
2. If the latch does not occur it may be necessary to pick up and repeat the process.
3. Do not set over 50 kips on the structural casing until the 20" has been cemented.

figure x (to be included)

20" Casing Setdown Weight

Cementing 20" Casing

MU ATC cement head on landing string.

Establish circulation. Pump a minimum of 2 x (string volume of DP + casing volume from DP to shoe) with seawater.

Hold pre-job safety meeting on cementing procedures with all parties involved.

Test cement lines to 3000 psi.

Cement 20" casing using the cement slurries specified in Section I of this program. Recalculate based on actual well data.

table x (to be included)

Cement slurry data

Take the following precautions:

1. Use only seawater or drillwater as specified in the cement slurry blend provided by the cementing company lab.
2. Use the cementing pump for the entire operation.
3. Pump rate: maintain at 5–6 bpm to avoid fracturing formation (slowdown if necessary to maintain returns to seafloor).
4. Use ROV to observe cement returns.
5. Pump 100 bbls preflush + sodium metasilicate (or equivalent) to color the preflush.
6. Pump required volume of lightweight lead cement – do not cut short.
7. Pump required volume of tail cement – do not cut short.

After pumping cement, release the ATC drillpipe wiper dart pumping with cementing unit.

Switch to the rig pumps and displace at higher rate, 25-30 BPM. Slow to 5 BPM for final 10 bbls.

Shift the sleeve in the ATC Dart Catcher, and pump an additional 10.5 bbls. displacement for TOC at 30' above float shoe

Slowly slack off the weight of the casing string – monitor for settling with ROV. If settling is observed, hold with DP for 4 hours or until surface cement samples set (set surface samples in refrigerator to approximate seafloor temperature).

Adjust the heave compensator to support about 2,000–3,000 lbs more than running string, WHRT, and cementing stinger weight. Release WHRT per VETCO operations manual and on-site VETCO service technician. When the tool releases, the heave compensator will stroke closed lifting the tool free from the housing.

POOH and lay down WHRT.

1. Strap out of the hole to get a precise wellhead measurement. Report the top of the WH on the daily drilling report.
2. Examine the WH for debris or flow with ROV. Check bull’s-eye and record both angle and direction on the daily drilling report.
3. Flush WH with the inner cementing string one stand below the wellhead.

Close valves on wellhead.

BOP Stack and Marine Riser Running Procedures:

Out of critical path:

• Test non-subsea related BOP equipment. Install bull’s-eye on BOP and record reading for future reference.
• Stump test BOP Stack to the following pressures using water and function test from both pods.
  • Ram preventers: LOW = 200 / 10000 HIGH
  • Annular preventers: LOW = 200 / 66% of WP High
• Attached funnel to bottom of BOP stack connector.

Winch rig to safe zone before running BOP stack and marine riser.

Hold pre-job safety meeting on handling and running procedures for BOP stack, LMRP, and marine riser with all parties involved. Adhere to weather limitations as per rig-specific operations manual supplement.

Rig up BOPS.

a) Install the methanol / glycol injection umbilical for the H-4 connector ROV quick stab. Stab umbilical into ROV port. Colored methanol / glycol will be pumped through the umbilical to flush connector cavity at ±7 day intervals. Glycol is preferable.
b) Verify H-4 connector has new-style VETCO hydrate lip seal.
c) Insure funnel is install on bottom of BOP stack connector assembly.

Run the BOPS and riser.

a) Record hook load every joint while running riser. Also record weights for the TDS/Traveling Block, riser running tool, tensioning ring (if not integral to telescopic joint), and diverter housing/upper flex joint. Send data to Drilling Engineer for review.
b) Do not install automatic riser fill valve joint in the riser string.
c) Test choke and kill lines to 200 / 7500 psi unless higher pressures are indicated. Test at start, halfway to subsea wellhead, and at wellhead.
d) Pick up slip joint (closed) and landing joint and record buoyed weight of the BOPS and riser. Report weight of BOP and riser on daily drilling report. Notify office immediately if actual weight and estimated riser weight figures differ by more than 30 kips.
e) Rig up goosenecks, and sheaves for BOP hydraulic hoses. Install tensioners.

Winch rig from safe zone to location of the wellhead..

Land and latch BOP Stack

1. Always land BOP stack with slip joint closed.
2. While observing with the ROV, land and latch the stack.
3. Overpull 50 kips to verify the latch.
4. Record BOP and riser bull’s-eyes and report readings on the daily drilling report. Notify office if bull’s-eye is over 1.0°.
5. Space slip joint at ½ stroke to prevent damage caused by riser recoil during disconnect.

Test BOPS and Casing.

1. Test wellhead connector, shear rams, and casing to 250 / 3970 psi surface pressure while laying down the landing joint. Pressure must not decline by more than 10% in 30 minutes.
2. Test rams and choke manifold to 250 / 7500 psi. Test annular preventers to 250 / 3500 psi
3. Function Test BOPS from both pods.

Adjust riser tensions, un-scope slip joint, and rig up the diverter.

Note the minimum required tension and maximum tension.

Note the % offset assumed for the minimum required tension. If this % offset is exceeded at any point, contact the office to obtain applicable top tension requirements for greater offsets.

Note the riser collapse rating and maximum allowable evacuation (w/ SF = 1). Maximum flex joint angle is 4.0 degrees.

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Best Drilling Practices Recommendations for All Hole Sections

• Hole maintenance is vitally important.
• Do not sacrifice hole maintenance for incremental reductions in overall time. Recent experience shows that shortcutting standard oilfield practices actually contributes to NPT.
• The well design with multiple liners provides several areas in which cuttings beds will accumulate. It is advisable to clean these areas during each trip out of the hole.
• Wiper trips should be made on a routine basis to prevent cuttings beds from accumulating in the directionally drilled portion of the hole.
• Conditioning trips should be made before POOH at all casing points.
• 20' - 25' for rat hole is sufficient below long strings of casing, and 5' is sufficient below the liners. This limits the length of oversized, open hole below casing shoes where cuttings can accumulate. It also prevents excessive cement slump that can detrimentally effect the shoe test upon drilling out that can be a problem given the recommended cement slurry densities vs. the planned section TD MWs.

Rotary Steerable Drilling RPM

• Drill with a minimum of 120 rpm with the Baker Autotrack system. If possible increase to 150 – 180 rpm. Balance ECD with the higher RPM. Watch for vibrations at the higher RPM and backoff the rpm to remove excessive vibrations.

Rotary Steerable Circulating Off Bottom RPM

• When circulating off bottom (hole conditions permitting) increase the rpm to ABOVE the on-bottom rpm for increased hole cleaning (ie at least 150-180 rpm). Watch for vibrations at the higher RPM and backoff the rpm to remove excessive vibrations.

Hole Condition Monitoring

• When the bit is OFF BOTTOM, at the rig record the surface torque, rotating string weight, and pick up and slack off readings on every other connection. Baker will provide a predicted rotating torque plot off bottom. Plot the predicted vs actual on a graph (Y axis depth; x axis surface tension). Monitor hole cleaning using the chart. If the trend lines start diverging away from the predicted then hole cleaning problems are occurring.

Pumping Sweeps

• When pumping a sweep pull the bit off bottom prior to the sweep exiting the bit. Ensure the drill string is at least 60 RPM while the sweep exits the bit. Increase the drill string rotation to a minimum of 120 RPM while pumping the maximum GPM while the sweep is moving up the annulus. Consider pumping piggyback sweeps by using a low vis then high vis sweep.

Circulating Bottoms Up

• Always CBU with a maximum pump rate and maximum RPM (if possible above 150 RPM) while reciprocating the pipe. It may take up to 4 times bottoms up to clean the hole. Don’t just circulate a predetermined volume (ie 1.5 bottoms up) but circulate until the hole is clean. Don’t substitute reduced circulating time with the thought that we can backream if we see a problem.

Tripping Out of the Hole

• After circulating the hole clean, while POOH if a tight spot or swab is encountered, always first assume it is a cuttings bed problem (hole cleaning related). Steps for tight hole while tripping out:
  • Circulate the hole clean as many bottoms up as needed.
  • POOH without the pumps or rotation.
  • If a tight spot is encountered, DO NOT TURN ON THE PUMPS OR ROTATE AT THE TIGHT SPOT. TIH to clear the BHA from the tight spot. Circulate at max GPM and max rpm for 30 minutes. Again POOH slow without the pumps or rotation. If the tight spot is gone, it was a cuttings bed problem and we just moved it up the hole. Stop and circulate at max GPM with max rpm at least bottoms up until the hole is clean. If the tight spot is still there, then carefully backream as required.

Backreaming and Pumping Out

• Pumping out of the hole without drill pipe rotation is generally unacceptable and leads to backreaming conditions which often leads to packoffs and lost circulation. Pumping out without rotation can cause a cuttings bed above the BHA. If pumping is needed consider TIH a few stands and maximize GPM and rpm while pumping. Circulate clean then POOH without the pumps or rotation.
• Backreaming often creates cuttings beds above the BHA (due to slow rpm) even with high GPM. Attempt to maximize the GPM, rpm, and slow rate of POOH while backreaming. If prolonged backreaming occurs consider stopping after a few stands and TIH the circulate at max GPM and rpm the hole clean then resume backreaming. Repeat as needed. After backreaming, never POOH without circulating the hole clean with max GPM and rpm.

---

17" x 20" Hole and 16" Casing
xxx' - xxx' TVD RKB (xxx' – xxx' BML)

 

Hold pre-job safety meeting on handling BHA tools with all parties involved.

L/D 26" BHA. P/U 17" bit, in-line underreamer, and BHA as specified in Section F of this program.

17"x 20" BHA

• 17" Bit - 20" Security NBR
• 12 3/4" Motor - 16 1/2" NM STB
• 9 1/2" MWD/LWD - NM Screen Sub
• 16 1/2" NM STB
• 1 x 9 1/2" NMDC - 2 x 9 1/2" DC
• XO
• 3 x 8" DC
• XO
• 9 x 6 5/8" HWDP
• 6 1/2" Hydraulic Jars
• 8 x 6 5/8" HWDP
• 5 1/2" DP

Note: The minimum ID encountered in the 20" casing is the Vetco Landing Collar for the 16" liner. The ID is 17.135" with a drift diameter of 17".

RIH. Test MWD and LWD, if run. TIH and tag the top of cement. Record the TOC depth on the daily drilling report.

Displace to NAF Mud

Hole Section Mud Properties:
Fluid Type: NAF
MW                PV             YP            ES          Alkalinity        Chlorides              HTHP          LGS
10.0 - 10.4      6 - 18        16 - 20      >450      ≥5 ppb          250K - 275K         <4cc           <6%

Hold pre-job safety meeting on displacement procedures and NAF with all parties involved.

Inspect NAF transfer hoses, clean out the mud pits. If more than 10-15 bbl of water remains in the pits, add 1-2 sacks of calcium chloride, and put 40-50 mesh screens on shale shakers for initial circulation of thick NAF.

Take on NAF from boat(s). Verify condition and volume of NAF in the pits. Shear and treat as required.

Displace choke and kill lines to NAF.

Displace hole to NAF.

1. Pump NAF at 1200 gpm. Reduce rate if pressures are increasing or if returns run over the shakers. Do not stop pumping once the displacement has commenced unless absolutely necessary.
2. Rotate and reciprocate pipe during displacement.
3. Test for interface every 15-20 min. until 75% of hole is displaced, then test continuously.
4. When clean NAF returns are seen, record strokes, start shakers, and route NAF to pits. Calculate how much water was left in the hole from stroke count.
5. Dump NAF-free water-based fluids. Incorporate remaining interface into the mud system.

Begin remedial treatments as required. Add emulsifier and wetting agents at the shakers or at the suction (or both locations in case of severe contamination) as needed.

Change out shaker screens to the smallest mesh possible as soon as it appears the shakers can handle it.

Drilling 17" x 20" Hole

Drill cement out of 20" casing and 20" float shoe.

1. Adjust mud weight while drilling cement.
2. Maintain mud properties.
3. Before drilling the shoe, break circulation and circulate prior to taking slow pump rates. Check and record choke and kill line friction pressures. Perform power choke drill.

Drill out 10' of new hole. To avoid packing-off below the surface casing, pump a 200 bbl x 200 vis super-sweep (to clear the rat hole below the 20" casing) while mechanically disturbing the rat hole area by rotating a bit/stabilizer across the area at high rpm.

Pull to shoe.

Conduct LOT. The expected LOT is 10.7 ppg. If actual LOT is less than an expected, contact the office and prepare to squeeze shoe.

Once a LOT is obtained and drilling commences, pump 100 bbl x 200 vis supersweeps as necessary but at least prior to connections for 1st 300' of 17 ½" x 20" hole drilled.

Drill ahead to 17" x 20" hole TD at 7000' TVD/MD RKB.

1. Once NBR clears the casing shoe, open reamer per SecurityDBS procedure (Delivery Pending).
2. Maintain mud properties, with special emphasis on the 6 RPM reading.
3. Use 6 ½" mud pump liners and sufficiently large mesh shaker screens to ensure ability to sweep the hole and handle the increased amount of cuttings at the surface.
4. Flow rate: 900 - 1025 gpm. Boost riser.
5. WOB: 10 - 20 K
6. RPM: 120 - 180
7. ROP: +/-60 ft/hr. Use PWD to maintain average ECD 0.5 ppg less than 20" LOT and ECD surge pressures below 20" LOT.
8. Pump 100 bbl (or slugging pit volume) viscous and/or weighted NAF "supersweeps" every stand for the first 300' and at least every 2 stands thereafter.
9. Take MWD directional survey readings every stand.
10. Make short wiper trips prior to interval TD especially if required by hole conditions.
11. Raise MW as hole conditions dictate.
12. Drill hole to fit casing tally with 20' - 25' of rat hole below casing shoe. Do not drill more than 50' beyond APD shoe depth.
13. Have LCM available to combat lost returns.
14. If wiper trip is required before reaching TD, pump and back ream out the first few stands or to the casing shoe, whichever is closest.

 At section TD, perform wiper trip only if warranted by hole conditions. Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up.

The drilling BHA will leave approx. 4' of undergauge hole due to the the bit and NBR spacing.

If casing is to be run without logging or another trip for mud conditioning, condition mud properties for casing running.

POOH SLM

Running 16" Casing (16" 109 PPF P-110 Big Omega SC)

Out of the critical path, install Protech/Centerform composite centralizers on 16" casing joints per the program included in Section E.

Trip in hole and pull 18 3/4" nominal seat protector (NSP):

• Trip in hole with jet sub, WBRT (wear bushing running/retrieving tool), and casing landing string.
• Wash WH area and sweep with large volume hi-vis pill while boosting the riser.
• Limit overpull to 50 kips. Allow NSP to work it self out slowly.
• Rabitt landing string using 2 5/8" drift to ensure the cement plug ball and dart will pass.

Make up and stand back the casing hanger/seal assembly running tool, cementing plug assembly, and the 16" casing hanger and pack off seal. Ensure the lead impression block is used on the VETCO running tool to verify proper seal setting.

• Use 20' extension pup joint to permit standing back PADPRT and wiper plug assembly.
• Drift OD of plug launching balls/darts (ensure the landing string has been drifted to the required ID, 2 5/8").

DO NOT FORGET TO INCLUDE THE CASING HANGER AND ANY EXTENSION IT MAY HAVE TO THE CASING TALLY.

Make up and stand back cementing head ahead of time, see landing string/cementing head stackup diagram in Section E of this program.

Hold pre-job safety meeting on running casing with all parties involved. Verify the running string design provides adequate capacity for the planned use.

If casing length is greater than riser length, have casing x running string crossover(s) on rig floor. Also have full-opening safety valve for running string in open position and ready to stab, if needed.

PU and MU 16" casing. When making up Big Omega SC type connections, MU Torque should be 17500 ft-lbs.

16" Casing String

• Guide Shoe
• 3 Jt. 16" 109# P-110 Big Omega SC Pin x Big Omega SC Box
• Autofill Float Collar
• 6 Jts. 16" 109# P-110 Big Omega SC Pin x Big Omega SC Box
• ATC Wiper Plug indicator Sub
• Approx. 48 Jts. 16" 109# P-110 Big Omega SC Pin x Big Omega SC Box
• Vetco 16" Hanger

Note: Hanger may already be bucked onto a full joint of 16" casing.

 Run casing on approx. xxx' of 5 1/2" 21.90 ppf run immediately above the 16" casing hanger and 5 1/2" 38 ppf landing string to surface.

Note: Only xxx' of 5 1/2" landing string will be on board. Additional length of 5 1/2" 21.90 ppf DP can safely be run below wellhead to land 16" casing in the hanger.

• Protech/Centerform composite centralizers will be Installed on the 3 joints to run as the shoe track and the 2 joints immediately above. 2 backup joints will also have the centralizers.
• Threadlock all connections on shoe track.
• Apply light coat of AP-5 grease or lead-free API-modified thread compound to each connection, but do not use API or other metallic-base thread compound.
• Fill the casing while picking up the next joint and ensure the casing is full every 5 joints.
• Install the ATC Diverter Sub 1 stand above the casing running tool in the landing string.

Collapse Caution: It is imperative that the casing string and drill pipe running string be full of fluid while running. Once the 16” shoe has entered the wellhead housing, pump at least 1 1/2 casing volumes to assure that the strings are full.

• Trip at ±2 min/std when casing is below WH to prevent lost returns at the 20" shoe.
• Space out leaving 20' - 25' of rat hole below the 16" shoe. There will be approx. 4' of undergauge hole at TD that should be included in this rat hole spacing.

Make up the cementing equipment, casing hanger, pack-off and casing hanger/seal assembly running tool to the casing.

Continue to run the casing string until the hanger lands on the landing collar in the 20" casing.

• Once casing entes the open hole, slow to ±3 min/std.
• Drop 2 1/4" ball to convert ATC Diverter Sub for normal circulation 5 stands from bottom.
• As casing nears bottom, reduce running speed to no more than 12 feet per minute. Check the space-out measurements.
• If casing starts to take weight, wait for ball to seat in ATC Diverter Sub, convert sub to normal circulation, and wash to bottom
• If lost circulation occurs after landing out 16" hanger, pick-up 16" casing string 5', re- establish circulation, and set back down. Check space-out.

Cementing 16" Casing

After landing in the casing hanger, makeup the ATC Cement head on drillpipe and begin pumping to close the diverter. The 2 1/4" ball will be on the seat in the Diverter Sub, pressure up to 1000 psi and hold same for 2 to 3 minutes. Continue to increase pump pressure until the ball yields the seat at 2200 to 2600 psi.

The 2 1/4” ball will fall to the ATC Dual Plug System where it will land in a yieldable seat. Pressure up to 600 psi to test the VETCO Subsea Running Tool while shifting the isolation sleeve. Continue to increase the pressure until the seat yields at 800-1200 psi. This will launch the 3 1/2" OD drop ball from the Plug System.
Continue to pump the 3 1/2" ball until it lands in the seat in the Davis-Lynch float collar. Convert the float collar as per Davis-Lynch recommendations. After activating the valves in the float collar, the ball seat assembly will fall to the Guide Shoe.

Note: Due to the low shear value of the float equipment you may not see the sleeve activated.

Break circulation: circulate (minimum 2.0 x bottoms up from TD to Wellhead). Boost riser.

Hold pre-job safety meeting on cementing procedures with all parties involved.

Cement 16" casing using the cement slurries specified in Section I of this program. Recalculate based on actual well data.

table x (to be included)

Cement Slurry Data

NOTE: Gas anti-migration cement will be considered for use if any hydrocarbons are in the open hole.

• Use only seawater or drill water as specified in the cement slurry blend provided by the cementing company lab.
• Pump required NAF spacer preflush(es) (test cement lines to 5000 psi).
• Drop lower dart to release bottom wiper plug.

Approximately 5-10 barrels prior before the bottom DP dart reaching the ATC Diverter Sub slow the pump rate to 5 BPM. The pressure required to yield the seat in the Diverter with the pump down plug should range from 500-800 psi above the circulating rate.

After yielding the seat, continue to pump the Bottom DP dart down to ATC 16” SS Plug System ( Bottom Plug ). The Bottom DP dart will release the Bottom Plug at 800-1400 psi above circulating pressure. After the Bottom Plug is released, continue with the displacement.

Approximately 5-10 barrels prior to the calculated Bottom Plug displacement to the WPI, slow the pump rate to 3 bbls per minute.

When the Bottom ATC Casing Wiper Plug reaches the ATC WPI, 700-1000 psi pressure should be applied to activate the Plug Circulating system. The plug will shift to the open position and displacement can be resumed at normal pumping rates.

• Pump required cement as detailed in Section I of this program.
• Drop upper dart to release upper wiper plug.
• Pump required NAF post-spacer and displace with drilling fluid to displace dart to subsea plug basket and launch the top wiper plug (cement pumps).

Approximately 5-10 barrels prior before the Top DP dart reaching the ATC Diverter Sub slow the pump rate to 5 BPM. The pressure required to yield the seat in the Diverter with the pump down plug should range from 500-800 psi above the circulating rate.

After yielding the seat, continue to pump the Top DP Dart down to ATC 16” Plug System ( Top Plug ). The Top DP dart will release the Top plug at 1400-1800 psi above circulating pressure. After the Top Plug is released, continue with the displacement.

• Record pressure required to shear the plug.

Continue with displacement. Approximately 5-10 barrels prior to the calculated Top Plug displacement to the WPI, slow the pump rate to 3 bbls per minute.

• Switch over to rig pumps for displacement. Pump at 6-9 bpm, slowing down to 1-2 bpm for the last 10 bbl. Pump calculated displacement volume.

When the Top ATC Casing Wiper Plug reaches the WPI, the plugs will latch/lock/non- rotate together & 2600-3000 psi pressure should be applied to activate the WPI system.

Resume the displacement making appropriate corrections to the total casing displacement and bump (latch/lock/non-rotate) the plugs with 1000 psi.

• If wiper plug fails to bump, do not over displace. Do not test casing after bumping plug to avoid a wet shoe if plug leaks. Check the floats.

With 5000 lbs down weight, rotate the running string 3 1/2 turns to retract the cam ring and disengage it from the lock ring.

Set a minimum of 30000 lbs down to shear the pins releasing the packoff assembly from the running position and driving it into the seal pocket. 6000 lbs is required to energize the seals. With the seal properly seal, mating profiles on the packoff nut and casing hanger body engage as a positive mechanical lock-down.

P/U and RIH with jet sub, WBRT, and test-type 13 3/8" wear bushing. Wash WH thoroughly with jet sub and jet nozzle joint. Install wear bushing. POOH.

Following a minimum WOC time of 6 hrs. with the drillstring above the BOPS, test BOP blind rams and casing as follows:

• Blind rams and casing: 250 / 3372 psi.
• Pressure must not decline more than 10% in 30 minutes.
• 16" hanger and seal assembly are rated to 5000 psi.

---

14 1/2" x 17 1/2" Hole and 13 5/8" Casing

xxx' - xxx' TVD RKB (xxx' – xxx' BML)

Drilling 14 1/2" x 17 1/2" Hole

Hold pre-job safety meeting on handling BHA tools with all parties involved.

L/D 26" BHA. P/U 14 1/2" bit, in-line underreamer, and rotary steerable BHA as specified in Section F of this program.

14 1/2" x 17" BHA:

• 14 1/2" Bit - 9 1/2" Autotrak
• 9 1/2" MWD/LWD w/ Mod STB + BCPM
• NM Screen Sub
• 14 3/8" STB
• 17 1/2" Rhino Reamer
• Float Sub - 1 x 9 1/2" DC
• 14 3/8" STB
• 2 x 9 1/2" DC
• XO
• 3 x 8" DC
• XO
• 9 x 6 5/8" HWDP
• 6 1/2" Hydraulic Jars
• 8 x 6 5/8" HWDP
• 5 1/2" DP

Note: The ID of the 16" 109 ppf casing is the 14.688" with a drift diameter of 14.50".

RIH. Test MWD and LWD, if run. TIH and tag the top of cement. Record the TOC depth on the daily drilling report.

Drill cement out of 16" casing and 16" float shoe.

• Maintain mud properties.
• Before drilling the shoe, break circulation and circulate prior to taking slow pump rates. Check and record choke and kill line friction pressures. Perform power choke drill.

Drill out 10' of new hole. To avoid packing-off below the surface casing, pump a 200 bbl x 200 vis super-sweep (to clear the rat hole below the 16" casing) while mechanically disturbing the rat hole area by rotating a bit/stabilizer across the area at high rpm.

Pull to shoe.

Conduct LOT. Expected LOT is 12.4 PPG. If LOT is less than an expected, contact the office and prepare to squeeze shoe.

Once a LOT is obtained and drilling commences, pump 100 bbl x 200 vis supersweeps as necessary but at least prior to connections for 1st 300' of 14 1/2" x 17" hole drilled.

Drill ahead to 14 1/2" x 17" hole TD. KOP for the directional program is xxx' MD/TVD RKB.

Hole Section Mud Properties:
Fluid Type: NAF
MW              PV           YP            ES         Alkalinity      Chlorides       HTHP     LGS

10.4-11.5       10-22      14-18       >450     > 5 ppb       250-275 K      < 3cc     <6%

11.5-12.0       12-25      14-18       >450     > 5 ppb       250-275 K      < 3cc     <6%      

1. Once Rhino Reamer clears the casing shoe, drop ball and open reamer per Smith procedure (Delivery Pending).
2. Maintain mud properties, with special emphasis on the 6 RPM reading.
3. Use 6 1/4" or 6" mud pump liners and sufficiently large mesh shaker screens to ensure ability to sweep the hole and handle the increased amount of cuttings at the surface.
4. Flow rate: recommended 900 - 1025 gpm. Boost riser.
5. WOB: 10-25 kips
6. RPM: 120-150
7. ROP: +/- 60 ft/hr. Use PWD to maintain average ECD 0.5 ppg less than 16" LOT and ECD surge pressures below 16" LOT.
8. Pump 100 bbl (or slugging pit volume) viscous and/or weighted NAF "supersweeps" every stand for the first 300' and at least every 2 stands thereafter.
9. Take MWD directional survey readings every stand.
10. Make wiper trips prior to interval TD only if required by hole conditions.
11. Raise MW as hole conditions dictate.
12. Drill hole to fit casing tally with 20' - 25' of rat hole below casing shoe. Do not drill more than 50' beyond APD shoe depth, 9600' TVD / 9692' MD RKB.
13. Have LCM available to combat lost returns.
14. if wiper trip is required before reaching TD, pump and backream out the first few stands or to the casing shoe, whichever is closest.

At section TD, perform wiper trip only if warranted by hole conditions. Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up.

The drilling BHA will leave 75.7' of undergauge hole due to the Autotrak and LWD placement between the bit and NBR.

POOH SLM and change BHA so that NBR can ream most of undergauge portion of the hole for running casing.

Ream undergauge portion of the hole to eliminate excessive rat hole. This will leave approx. 3' of undergauge hole due to bit-NBR spacing. If casing is to be run without logging or another trip for mud conditioning, condition/thin mud properties for casing running.

POOH SLM and compare to previous tally.

Running 13 5/8" Casing - (13 5/8" 88.2 PPF Q-125 Hydril SLX)

Out of the critical path, install Protech/Centerform composite centralizers on 13 5/8" casing joints per the program included in Section E.

Trip in hole and pull wear bushing:

1. Trip in hole with jet sub, WBRT (wear bushing running/retrieving tool), and casing landing string.
2. Wash WH area and sweep with large volume hi-vis pill while boosting the riser.
3. Limit overpull to 50 kips. Allow wear bushing to work it self out slowly.
4. Drop drift to ensure landing string will pass the cement plug ball and dart. POOH.

Make up and stand back the casing hanger/seal assembly running tool, cementing plug assembly, and the 13 5/8" casing hanger and pack off seal. Ensure the lead impression block is used on the VETCO running tool to verify proper seal setting.

• Use 20' extension pup joint to permit standing back PADPRT and wiper plug assembly.
• Drift OD of plug launching balls/darts (ensure the landing string has been drifted to the required ID, 2 5/8").

DO NOT FORGET TO INCLUDE THE CASING HANGER AND ANY EXTENSION IT MAY HAVE TO THE CASING TALLY.

Make up and stand back cementing head ahead of time, see landing string/cementing head stackup diagram in Section E of this program.

Hold pre-job safety meeting on running casing with all parties involved. Verify the running string design provides adequate capacity for the planned use.

If casing length is greater than riser length, have casing x running string crossover(s) on rig floor. Also have full-openg safety valve for running string in open position and ready to stab, if needed.

PU and MU 13 5/8" casing. Recommended MU Torque is 48000 ft-lbs.

Run casing on 5 1/2" 38 ppf landing string:

13 5/8" Casing String

• Guide Shoe
• 3 Jt. 13 5/8" 88.2# Q-125 SLX Box x SLX Pin w/ Protech centralizers
• Autofill Float Collar
• 2 Jts. 13 5/8" 88.2# Q-125 SLX Pin x SLX Box w/ Protech centralizers
• 7 Jts. 13 5/8" 88.2# P-110 SLX Pin x SLX Box
• ATC Wiper Plug Indicator Sub
• Approx. 13 Jts. 13 5/8" 88.2# P-110 SLX Pin x SLX Box
• Approx. 133 Jts. 13 5/8" 88.2# Q-125 SLX Pin x SLX Box
• Vetco 13 5/8"MS-700 Casing Hanger

Note: Hanger may already be bucked onto a full joint of 13 5/8" casing.

1. Protech/Centerform composite centralizers will be Installed on the 3 joints to run as the shoe track and the 2 joints immediately above. 2 joints to be run below the casing hanger will also have the centralizers installed. 2 backup joints will also have the centralizers.
2. Threadlock all connections on shoe track.
3. Be sure that lift nubbins are available for handling the casing.
4. Apply light coat of Bestolife 2000 thread compound to each connection.
5. Apply proper make-up torque to all connections.
6. Trip at ±1 min/std when casing is above the 16" casing hanger. Slow to ±2 min/std when casing is being run in the 16" casing.
7. Run ATC autofill sub 1 stand up in running string.
8. Space out leaving 20' - 25' of rat hole below the 13 5/8" shoe. There will be approx. 3' of undergauge hole at TD that should be included in this rat hole spacing.

Make up the cementing equipment, casing hanger, pack-off and casing hanger/seal assembly running tool to the casing.

Continue to run the casing string until the hanger lands in the 18 ¾" WH.
a) Once casing enters the open hole, slow to ±3 min/std.
b) Drop 2 1/4" ball to convert ATC Diverter Sub for normal circulation 5 stands from bottom.
c) As casing nears bottom, reduce running speed to no more than 12 feet per minute. Check the space-out measurements.
d) If casing starts to take weight, wait for ball to seat in ATC Diverter Sub, convert sub to normal circulation, and wash to bottom

figure x (to be included)

13 5/8 Casing Setdown Weight

Cementing 13 5/8" Casing

After landing in the casing hanger, makeup the ATC Cement head on drillpipe and begin pumping to close the diverter. The 2 1/4" ball will be on the seat in the Diverter Sub, pressure up to 1000 psi and hold same for 2 to 3 minutes. Continue to increase pump pressure until the ball yields the seat at 2200 to 2600 psi.

The 2 1/4” ball will fall to the ATC Dual Plug System where it will land in a yieldable seat. Pressure up to 600 psi to test the VETCO Subsea Running Tool while shifting the isolation sleeve. Continue to increase the pressure until the seat yields at 800-1200 psi. This will launch the 3 1/2" OD drop ball from the Plug System.
Continue to pump the 3 1/2" ball until it lands in the seat in the Davis-Lynch float collar. Convert the float collar as per Davis-Lynch recommendations. After activating the valves in the float collar, the ball seat assembly will fall to the Guide Shoe.

Note: Due to the low shear value of the float equipment you may not see the sleeve activated.

Break circulation: circulate (minimum 2.0 x bottoms up from TD to Wellhead). Boost riser.

Hold pre-job safety meeting on cementing procedures with all parties involved.

Cement 13 5/8" casing using the cement slurries specified in Section I of this program. Recalculate based on actual well data.

Table x (to be included)

Cement Slurry Data:

NOTE: Gas anti-migration cement will be considered for use if any hydrocarbons are in the open hole.

• Use only seawater or drill water as specified in the cement slurry blend provided by the cementing company lab.
• Pump required NAF spacer preflush(es) (test cement lines to 5000 psi).
• Drop lower dart to release bottom wiper plug.
  • Approximately 5-10 barrels prior before the bottom DP dart reaching the ATC Diverter Sub slow the pump rate to 5 BPM. The pressure required to yield the seat in the Diverter with the pump down plug should range from 500-800 psi above the circulating rate.
  • After yielding the seat, continue to pump the Bottom DP dart down to ATC 16” SS Plug System ( Bottom Plug ). The Bottom DP dart will release the Bottom Plug at 800-1400 psi above circulating pressure. After the Bottom Plug is released, continue with the displacement.
  • Approximately 5-10 barrels prior to the calculated Bottom Plug displacement to the WPI, slow the pump rate to 3 bbls per minute.
  • When the Bottom ATC Casing Wiper Plug reaches the ATC WPI, 700-1000 psi pressure should be applied to activate the Plug Circulating system. The plug will shift to the open position and displacement can be resumed at normal pumping rates.
• Pump required cement as detailed in Section I of this program.
• Drop upper dart to release upper wiper plug.
• Pump required NAF post-spacer and displace with drilling fluid to displace dart to subsea plug basket and launch the top wiper plug (cement pumps).
  • Approximately 5-10 barrels prior before the Top DP dart reaching the ATC Diverter Sub slow the pump rate to 5 BPM. The pressure required to yield the seat in the Diverter with the pump down plug should range from 500-800 psi above the circulating rate.
  • After yielding the seat, continue to pump the Top DP Dart down to ATC 16” Plug System ( Top Plug ). The Top DP dart will release the Top plug at 1400-1800 psi above circulating pressure. After the Top Plug is released, continue with the displacement.
• Record pressure required to shear the plug.
  • Continue with displacement. Approximately 5-10 barrels prior to the calculated Top Plug displacement to the WPI, slow the pump rate to 3 bbls per minute.
• Switch over to rig pumps for displacement. Pump at 6-9 bpm, slowing down to 1-2 bpm for the last 10 bbl. Pump calculated displacement volume.
  • When the Top ATC Casing Wiper Plug reaches the WPI, the plugs will latch/lock/non- rotate together & 2600-3000 psi pressure should be applied to activate the WPI system.
  • Resume the displacement making appropriate corrections to the total casing displacement and bump (latch/lock/non-rotate) the plugs with 1000 psi.
• wiper plug fails to bump, do not over displace. Do not test casing after bumping plug to avoid a wet shoe if plug leaks. Check the floats.

Set 13 5/8" Seal Assembly and Test BOPS

Set and test the 13 5/8" seal assembly to 250 / 5000 psi. No leak is the only acceptable result.

P/U and RIH with jet sub, WBRT, and test-type 13 5/8" wear bushing. Wash WH thoroughly with jet sub and jet nozzle joint. Install wear bushing. POOH.

Following a minimum WOC time of 6 hrs. with the drillstring above the BOPS, test BOP blind rams and casing as follows:

• Blind rams and casing: 250 / 4683 psi.
• Pressure must not decline more than 10% in 30 minutes.

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12 1/4" x 15" Hole

xxx' - xxx' TVD RKB (xxx' – xxx' BML)

Drilling 12 1/4 " x 15" Hole

Hold pre-job safety meeting on handling BHA tools with all parties involved.

L/D 14 1/2" x 17" BHA. P/U 12 1/4" bit, in-line underreamer, and rotary steerable BHA as specified in Section F of this program.

12 1/4" x 15" BHA :

• 12 1/4" Bit - 9 1/2" Autotrak
• 12 1/8" Mod STB w/ flex jt.
• 9 1/2" MWD/LWD
• 11 3/4" Mod STB
• BCPM
• Stop Sub
• NM Screen Sub
• 11 3/4" STB w/ float
• NM SDC
• 15" Rhino Reamer
• 1 x 8" NMDC
• 11 3/4" STB
• 2 x 8" DC
• XO
• 24 x 5 1/2" HWDP
• 5 1/2" Hydraulic Jars
• 5 x 5 1/2" HWDP
• 5 1/2" DP

RIH. Test MWD and LWD, if run. TIH and tag the top of cement. Record the TOC depth on the daily drilling report.

Drill cement out of the 13 5/8" casing and drill out the 13 5/8" float shoe.

• Maintain mud properties as specified.
• Before drilling out the shoe, take slow pump rates. Check and record choke and kill line friction pressures. Perform power choke drill.

Drill out 10' of new hole, circulate bottoms up, and pull up to shoe.

Conduct LOT. Expected LOT is 14.2 ppg. If LOT is less than an expected, contact the office and prepare to squeeze shoe.

Drill ahead to 12 1/4" x 15" hole TD, 11150' TVD / 11569' MD RKB.

Hole Section Mud Properties:
Fluid Type: NAF
MW                    PV               YP            ES             Alkalinity       Chlorides          HTHP         LGS
12.0-13.0             16 - 32         12 - 16     >450        ≥5 ppb        250K-275K        <2cc          <6%

• Once the Rhino Reamer clears the casing shoe, drop ball and open reamer per Smith procedure (Delivery Pending).
• Use 6" mud pump liners and sufficiently large mesh shaker screens to ensure ability to sweep the hole and handle the increased amount of cuttings at the surface.
• Flow rate: 800 - 1025 gpm. Boost riser. Sands may be highly unconsolidated. Do not exceed the specified flow rates when close to sand reservoirs. Do not perform extended circulation with bit across sands (circulate bottoms up, then pick up above sand to complete circulation).
• WOB: 10 - 25K
• RPM: 120 -180
• ROP: +/-75 ft/hr Use PWD to maintain average ECD 0.5 ppg less than 13 5/8" LOT and ECD surge pressures below 13 5/8" LOT.
• Pump 50 bbl viscous and/or weighted NAF sweeps (FV > 100 sec) every stand for the first 100m and at least every 2 stands thereafter. Occasional sweeps should be pumped to check for cuttings buildup in the hole.
• Take MWD directional survey readings every stand. Ensure MWD is set to operate in the volume range to correspond to the programmed bit hydraulics requirements for this hole section.
• Make short wiper trips prior to interval TD especially if required by hole conditions.
• Raise MW as hole conditions dictate.
  NOTE: Take choke and kill line friction pressures any time the MW is raised.
• Drill sufficient rat hole below the bottom of the last target zone to ensure space for the logging tools.
• Drill hole to fit casing tally with 5' of rat hole below casing shoe. Do not drill more than 50' beyond APD shoe depth of 11150' TVD / 11569' MD RKB.
• Have LCM available to combat lost returns as specified in Appendix 2.
• If wiper trip is required before reaching interval TD, pump and backream out the first few stands or to the casing shoe, whichever is closest

At section TD, perform wiper trip. Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up.

POOH SLM and prepare to test BOPs.

Test BOPs with the casing hanger/seal assembly running tool to the following pressures:

• Rams preventers and other equipment: 250 / 7500 psi
• Annular preventers: 250 / 5000 psi
• Function test the BOP on the pod not used for the pressure test.
• Out of critical path: test choke manifold and standpipe manifold to 250 / 7500 psi.

Open Hole Logging:

Hold pre-job safety meeting on wireline logging with all parties involved.

Perform logging program as specified in Section 1 of this program.

Perform wiper trips between logging runs as hole conditions dictate.

Perform wiper trip upon completion of all logging runs.

The drilling BHA will leave 85' of undergauge hole due to the Autotrak and LWD placement between the bit and NBR.

Change BHA so that NBR can ream most of undergauge portion of the hole for running casing.

Ream undergauge portion of the hole to eliminate excessive rat hole. This will leave approx. 3' of undergauge hole due to bit-NBR spacing.Condition/thin mud properties for casing running.

POOH SLM and rabbit the DP using a 2 5/8” or greater OD drill pipe drift with +-120’ of wire attached and recover drift. Lay out any joints of drill pipe that do not drift. Compare to previous tally.

Stop and circulate in wellhead and BOP stack to clean any shale that might be dislodged while running the liner.

Running 11 7/8" Liner (11 7/8" 71.8 PPF HCQ-125 Hydril 511)

Out of the critical path:

• Install Protech/Centerform composite centralizers on 11 7/8" casing joints per the program included in Section E.
• Have Weatherford service personnel on location. Inventory all liner equipment and tools prior to running. Double-check all lengths, OD’s, and ID’s, with Weatherford Stab Up Drawing. Verify that all dimensions are compatible with the casing and well bore.
• Liner hanger should be pinned to +/- 2,000 psi. Verify setting pressure with Weatherford serviceman prior to job.

After logging, depending on logging duration and hole conditions, a complete wiper trip to TD (may need to stage into the hole after a long logging job) should be performed.

Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up. Condition the mud – DO NOT POOH until mud properties are within required specifications for running casing. Mud rheology may be thinned to below program specs prior to running casing.

Trip out of hole.

Hold pre-job safety meeting on casing running with all parties involved.

Verify that the running string design provides adequate capacity for the planned use.

If casing length is greater than riser length, have casing x running string crossover(s) on rig floor. Also have full-opENIng safety valve for running string in open position and ready to stab, if needed.

Run casing per the program (threadlock all connections on shoe track).

Make up and stand back the liner hanger/running tool and cementing plug assembly per instructions of cementing and Weatherford service personnel and their respective Field Service Manuals.

• Use a 20' extension pup joint if necessary to permit standing back subassemblies.
• Drift OD of plug launching ball/darts (ensure the landing string has been drifted to the required ID, 2 5/8").

Make up and stand back cement head, if not already racked back from previous job.

PU and MU 11 7/8" liner. Recommended MU Torque is 29000 ft-lbs.

11 7/8" Casing String :

• Guide Shoe
• 3 Jts. 11 7/8" 71.8# HCQ125 Hydril 511 Pin x 511 Box w/ Protech Centralizers
• Autofill Float Collar
• 2 Jts. 11 7/8" 71.8# HCQ125 Hydril Pin x 511 Box w/ Protech Centralizers
• 5 Jts. 11 7/8" 71.8# HCQ125 Hydril Pin x 511 Box
• ATC Wiper Plug Indicator Sub
• Approx. 45 Jts. 11 7/8" 71.8# HCQ125 Hydril 511 Pin x 511 Box
• Weatherford 11 7/8" Liner Hanger

Run the liner on 5 1/2" 21.90 ppf DP.

a) Protech/Centerform composite centralizers will be Installed on the 3 joints to run as the shoe track and the 2 joints immediately above. 2 backup joints will also have the centralizers.
b) Threadlock all connections on shoe track.
c) Be sure that lift nubbins are available for handling the casing.
d) Apply light coat of Bestolife 2000 thread compound to each connection.
e) Apply proper make-up torque to all connections.
f) Fill the casing while picking up the next joint, ensure the casing is full every 5 joints.
g) If necessary, place one pup joint with a radioactive tag approximately 300' above each reservoir to flag the sands. Pup joint placement should specified in the program addendum.

Make up liner hanger assembly. LEAVING ROTARY SLIPS SET ON LINER JOINT, pick up approximately 3 feet to verify that the setting tool and all connections are properly torqued up. Once this has been done, pull slips, slack off until PBR sleeve is accessible from the rig floor. Fill the Floating Junk Bonnet with clean water. DO NOT SET SLIPS ON SETTING SLEEVE / PBR. SET DRILL PIPE SLIPS ON SETTING TOOL LIFT SUB. Make up stand of drill pipe to the liner hanger assembly running tool and lower assembly into well. Record liner weight.

Run ATC Diverter Sub 2 stands above liner hanger running tool in the running string.

Continue to run the casing string to TD. Pick up 5' for rat hole. Check the space-out measurements.

• Run liner assembly into well. Install wiper rubber on drill pipe to prevent foreign matter from falling in the well bore.
• Caution should be taken when hanger assembly enters and travels through the BOP stack and wellhead assembly.
• Trip liner in the hole (to casing shoe) monitoring slack off speed and ensuring that assembly is kept full of fluid.
• When the 11 7/8” guide shoe reaches the 13 5/8” casing shoe, screw the top drive into the last stand before going out to open hole and get slow pump rates at 15 – 25 – 35 spm through the ATC Diverter Sub. After recording these pressures continue running the liner. Also record liner pick up, slack off, and static weights.
• If Liner rotation is anticipated being required in open hole, calculate maximum drill down torque. Liner thread maximum make-up torque, plus rotating torque established at the casing shoe on last trip out of the hole (Step 15 above) minus 20% safety factor = maximum drill down torque. (Rotate slowly at the shoe prior to entering open hole and record minimum torque required to maintain sustained rotation. This torque to be used as reference.
• Drop ball to convert ATC autofill sub and Davis Lynch float equipment for normal circulation 20 stands from bottom.

When the liner is one stand off bottom, screw the Top Drive in and start pumping slowly to close the ATC Diverter Sub. Keep the pipe moving down hole during this operation. The 1 3/4" ball will be on the seat so pressure up to 600 psi slowly and hold the same for 2 or 3 minutes. Then continue to increase the pump pressure until the ball yields the seat (1500-1800 psi). Note: You will be TIH very slowly when you perform these steps.

After blowing the ball through the seat go back to circulating at 15 spm and record the pump pressure once the returns have stabilized (Do not exceed 800 psi during this operations – the nominal setting pressure of the WCS liner hanger is 1600 psi). The 1 3/4" ball will drop into the ATC Liner Plug System and rest on top of the 3 1/2” ball.

Start washing the last stand to bottom. Wash the liner within 10' of total depth and stop to finish displacing the cuttings out of the liner (Note: This second pressure should be a minimum of 150 psi greater than the previous pump pressure at 15 spm.

Do not attempt to tag actual TD as bottom.

There will be approx. 3' of undergauge hole at TD that creates a false bottom.

The rat hole spacing should be above it.

Calculate amount of slack off required to transfer all the liner weight plus 30,000 lbs. of drill pipe weight onto the liner hanger. Space out drill string to put the Cementing Head a minimum of that distance from the rig floor once hanger is hung off and weight slacked off.

After reaching total depth with the liner, pick up ATC Cement Head and make up same. Start circulating at 30 spm, and record the pump pressure once the returns have stabilized.

Establish pick up and slack off weights. Reciprocate liner while circulating and conditioning mud / hole. (If well conditions permit, and operator has given approval, it is recommended that the pipe be reciprocated during the mud / hole conditioning. Ensure that the reciprocation stroke is not long enough to uncover any formation that must be isolated. This will ensure that inadvertently sticking pipe will not leave that formation uncovered. (It is imperative that the driller understand that the reciprocation stroke be a slow steady movement to prevent harmful pressure surges.)

If hole becomes sticky prior to cementing and/or, hole conditioning is complete, position liner at setting depth (+-5’ off bottom).

After the liner has been displaced, drop the 2 3/8" setting ball and pump same to ATC Diverter sub to land the ball in the ATC diverter sub. Continue to increase pump pressure until the ball yields the seat at 2200 to 2800 psi.

After blowing the ball through the seat the 2 3/8" ball will drop to the ATC Liner Plug System where the ball will land in a yieldable seat. At that time the WCS rep will pressure up in stages to set the hanger (hydraulic hanger set pressure = 1,600 psi). Hold the pressure while the WCS rep works the liner to check and determine if the Hydraulic Hanger is set.

Shut down circulation. With 10-20,000 lb. of drill string weight down on liner hanger, rotate 6-8 torque free turns to the right to release setting tool from the liner. Pick up stretch in pipe plus 5'-10' to see liner weight loss ensuring that setting tool is released from the liner. Note: Ensure that setting tool is not picked up high enough to remove packer actuator sub from the PBR extension. (Double check pick up on slick joint and Floating Junk Bonnet polish nipple)

Set 30,000 lb. of drill string weight back down on liner hanger, to prevent pump out forces of cement job from inadvertently pumping the setting tool out of the liner. Prepare to cement. (Note: Slack off weight will vary from job to job. The Weatherford serviceman will figure his pump out forces on setting tool and set down sufficient weight to overcome those pump out forces)

After verifying the hanger is set, the ATC rep will pressure up to blow the ball seat in the liner running tool. Continue to increase the pressure until the seat yields at 3400 psi and launches the 3 1/2” drop ball from the liner plug system simultaneously.

After launching the 3 1/2” ball go back to circulating a 30 spm and circulate the ball to float collar and activate same.

Circulate and condition the drilling fluid for the upcoming cement job. Recommend not circulating above 30 strokes per minute until the thick mud is above the liner assembly. Circulate bottoms up (minimum 2 x bottoms up from TD to liner top). Boost riser.

Cementing 11 7/8" Casing

Hold pre-job safety meeting on cementing procedures with all parties involved.

Cement 11 7/8" casing using the cement slurries specified in Section I of this program. Recalculate based on actual well data.

Table x (to be included)

Cement Slurry Data

• Use only seawater or drillwater as specified in the cement slurry blend provided by the cementing company lab.
• Test cement lines to 5000 psi.
• Pump required NAF spacer preflush(es) per the cementing program in Section I.
• Pump required cement as detailed in Section I of this program.
• Release the drillpipe dart at the tail of cement. When this dart leaves the cement head we will again see a 1500-2200 psi pressure increase as the dart exits the PLI. Minimum pump rate is 5 bpm at all times.
• Displacement will be with mud. NOTE: IF SYNTHETIC DRILLING FLUIDS ARE BEING USED COMPRESSIBILITY FACTORS, IF APPLICABLE, MUST BE ENTERED INTO DISPLACEMENT FIGURES. CONSULT WITH OPERATOR RIG SUPERINTENDENT AND /OR MUD ENGINEER TO OBTAIN THIS INFORMATION.
• Approximately 5 barrels prior to the drillpipe dart reaching the ATC Diverter Sub slow the pump rate to 5 bpm . The pressure required to yield the seat with the drillpipe dart should range from 1500 - 2000 psi (above the circulating pressure). After yielding the seat the drillpipe dart will latch the liner wiper plug. The pressure required to release the liner wiper plug will range from 1500 - 2000 psi (above the circulating pressure). Record pressure required to shear the plug. Continue with the displacement.
• Approximately 5 barrels prior to the calculated plug displacement to the WPI, slow the pump rate to 5 bbls per minute.
• When the ATC Liner Wiper Plug reaches the WPI, 700 to 1000 psi (above the circulating pressure) should be applied to activate the WPI system. Resume the displacement making appropriate corrections to the total liner displacement if necessary. An additional 150 psi circulating pressure may be seen during this final displacement.
• Approximately 5-10 barrels prior to the calculated plug displacement to the Auto-fill Float Collar, slow the pump rate to 5 bbls per minute
• When the plugs reach the float collar, 1000 psi pressure should be applied to the float collar/wiper plug system. Pump calculated displacement volume and do NOT over displace. DO NOT test casing after bumping plug to avoid a wet shoe if plug leaks
• Release pressure and check to insure that the float valves and/or liner wiper plug is holding.

Set 11 7/8" Liner Top Packer and Test BOPS

Pick up +- feet to release packer actuator sub from the PBR extension. Slack off to contact packer actuator dogs with top of PBR sleeve.

Set down minimum of 40000 lbs. (at liner top) to shear pins and energize the TSP packer (The packer actuator sub has rotational capability. Rotate drill string slowly to the right to change friction points and work weight down to the packer. Up to 100000 lbs. can be used to set packer if necessary.

Close rams, and put a quick test on liner top packer (800 – 1,000 psi). Hold test no longer than 3- 5 minutes if cement was calculated to reach up into lap of liner. (NOTE: Verify test procedures with Operator's rig superintendent. Some operators prefer to reverse out cement prior to putting a test on Liner Top Packer.)

Pick up setting string leaving the end of the setting tool right at the liner top Begin reversing out slowly. Once returns are obtained, pick up slowly until the end of the running tool is approximately 5 feet above the liner top. Increase pump rate and continue to pick up slowly until the end of the running tool is 10-15’ above the liner top. Once sufficient fluid has been reversed out to ensure that all excess cement (Calculated Volume) is out of annulus and either at surface or at least 2,000’ from the end of the setting tool (inside drill pipe), slow pump rate to 1-2 barrels per minute. Slowly slack off setting string inserting the end of slick stinger back into the end of the PBR tie- back extension at least 5-7 ft. Continue circulating for 3-5 minutes and then slowly pick up leaving the slick stinger 5-10 ft above the liner top. Increase pump to desired rate and complete reversing out. Reverse out two drill pipe volumes or until no cement returns are observed. Limit circulating pressure to psi while reversing out to prevent overloading the liner hanger. PRIOR TO JOB VERIFY WITH OPERATOR’S HOUSTON OFFICE THE INTENT TO REVERSE OUT EXCESS CEMENT. VERIFY WITH WEATHERFORD SERVICEMAN LIMITING CIRCULATION PRESSURES.

• Rotate and/or reciprocate drill pipe occasionally, while reversing out to ensure that drill string is free.
• If liner top did not test (if test was performed), and/or attempts to reverse out results in lost returns and/or pressure loss, or, if TSP packer was not set, DO NOT REVERSE OUT CEMENT AT LINER TOP. PULL 5-10 STANDS THEN REVERSE OUT.
• Plan to catch and discard cement-contaminated mud that is reversed to surface.
• MONITOR REMAINING CEMENT PUMPING TIME AS JOB PROGRESSES. IF LESS THAN 1 HOUR OF CEMENT PUMPING TIME REMAINS (INCLUDE ANTICIPATED REVERSE OUT TIME) WHEN LINER WIPER PLUG BUMPS AND PACKER IS SET, POOH WITHOUT REVERSING OUT CEMENT.
• ENSURE THAT SETTING TOOL HAS BEEN PULLED AT LEAST 15 STANDS ABOVE THE LINER TOP WITH NO LESS THAN ½ HOUR OF CEMENT PUMPING TIME REMAINING, IF REVERSING OUT OF EXCESS CEMENT IS NOT COMPLETE.
• VERIFY ITEMS D & E ABOVE WITH OPERATOR’S HOUSTON OFFICE PRIOR TO JOB.

Monitor well conditions. If well is stable, test liner top and/or POOH with drill pipe and liner setting tool as required.

POOH with liner hanger running tool.

Pick up and RIH with jet sub, WBRT, and test-type 9 5/8" wear bushing. Wash WH thoroughly with jet sub and jet nozzle joint. Install wear bushing. If seawater was used to displace cement: Circulate out NAF mud from the upper wellhead, BOPS, riser, and choke, kill and booster lines with seawater.

Following a minimum WOC time of 6 hrs. with the drillstring above the BOPS, test BOP blind rams and casing as follows:

• a) Casing / Shear Rams: 250 / 3035 psi
• b) Pressure must not decline more than 10% in 30 min.

---

9 7/8" x 12 1/4" Hole
xxx' - xxx' TVD RKB (xxx' – xxx' BML)

Drilling 9 7/8 " x 12 1/4" Hole

Hold pre-job safety meeting on handling BHA tools with all parties involved.

L/D 12 1/4" x 14" BHA. P/U 12 1/4" bit, in-line underreamer, and rotary steerable BHA as specified in Section F of this program.

10 5/8" x 12 1/4" BHA:

• 9 7/8" Bit
• 6 3/4" Autotrak
• 6 3/4" MWD/LWD w/ Mod STB + BCPM
• ORD
• CN
• Stop Sub
• NM Screen Sub
• 9 7/8" x 10 5/8" Concentric Reamer
• SDC
• 12 1/4" Security NBR
• 1 x 8" DC
• 10 1/2" STB w/ float
• 2 x 8" DC
• XO
• 24 x 5 1/2" HWDP
• 5 1/2" Hydraulic Jars
• 5 x 5 1/2" HWDP
• 5 1/2" DP

RIH. Test MWD and LWD, if run. TIH and tag the top of cement. Record the TOC depth on the daily drilling report.

Drill cement out of the 11 7/8" casing and drill out the 11 7/8" float shoe.

• Maintain mud properties as specified.
• Before drilling out the shoe, take slow pump rates. Check and record choke and kill line friction pressures. Perform power choke drill.

Drill out 10' of new hole, circulate bottoms up, and pull up to shoe.

Conduct LOT. Expected LOT is 14.9 ppg. If LOT is less than an expected, contact the office and prepare to squeeze shoe.

Drill ahead to 9 7/8" x 12 1/4" hole TD, 13450' TVD / 14431' MD RKB.

Hole Section Mud Properties:
Fluid Type: NAF
MW             PV                YP              ES            Alkalinity      Chlorides          HTHP     LGS
13.0-14.4      20 - 34        12 - 16        >450        ≥5 ppb        250K-275K        <2cc       <6%

• Once NBR clears the casing shoe, drop ball and open reamer per SecurityDBS procedure (Delivery Pending).
• Use 6" mud pump liners and sufficiently large mesh shaker screens to ensure ability to sweep the hole and handle the increased amount of cuttings at the surface.
• Flow rate: 550 - 650 gpm. Boost riser. Sands may be highly unconsolidated. Do not exceed the specified flow rates when close to sand reservoirs. Do not perform extended circulation with bit across sands (circulate bottoms up, then pick up above sand to complete circulation).
• WOB: 10 - 25 kips
• RPM: 120 -180
• ROP: +/-75 ft/hr Use PWD to maintain average ECD 0.5 ppg less than 11 7/8" LOT and ECD surge pressures below 11 7/8" LOT.
• Pump 50 bbl viscous and/or weighted NAF sweeps (FV > 100 sec) every stand for the first 100m and at least every 2 stands thereafter. Occasional sweeps should be pumped to check for cuttings buildup in the hole.
• Take MWD directional survey readings every stand. Ensure MWD is set to operate in the volume range to correspond to the programmed bit hydraulics requirements for this hole section.
• Make short wiper trips prior to interval TD especially if required by hole conditions.
• Raise MW as hole conditions dictate.
  • NOTE: Take choke and kill line friction pressures any time the MW is raised.
• Drill hole to fit casing tally with 5' of rat hole below casing shoe. Do not drill more than 50' beyond APD shoe depth of 13450' TVD / 14431' MD RKB.
• Have LCM available to combat lost returns as specified in Appendix 2.
• If wiper trip is required before reaching interval TD, pump and backream out the first few stands or to the casing shoe, whichever is closest

At section TD, perform wiper trip only if warranted by hole conditions. Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up.

POOH SLM and prepare to log.

Open Hole Logging

Hold pre-job safety meeting on wireline logging with all parties involved.

Perform logging program as specified in Section 1 of this program.

Perform wiper trips between logging runs as hole conditions dictate.

Perform wiper trip upon completion of all logging runs. Condition/thin mud properties for casing running.

The drilling BHA will leave 95' of undergauge hole due to the Autotrak and LWD placement between the bit and NBR.

Change BHA so that NBR can ream most of undergauge portion of the hole for running casing.

Ream undergauge portion of the hole to eliminate excessive rat hole. This will leave approx. 3' of undergauge hole due to bit-NBR spacing.

POOH SLM and rabbit the DP using a 2 5/8” or greater OD drill pipe drift with +-120’ of wire attached and recover drift. Lay out any joints of drill pipe that do not drift. Compare to previous tally.

Stop and circulate in wellhead and BOP stack to clean any shale that might be dislodged while running the liner.

Running 9 7/8" Liner (9 7/8" 65.1 PPF T-95 Hydril SLX)

Out of the critical path:

• Install Protech/Centerform composite centralizers on 11 7/8" casing joints per the program included in Section E.
• Have Weatherford service personnel on location. Inventory all liner equipment and tools prior to running. Double-check all lengths, OD’s, and ID’s, with Weatherford Stab Up Drawing. Verify that all dimensions are compatible with the casing and well bore.
• Liner hanger should be pinned to +/- 2,000 psi. Verify setting pressure with Weatherford serviceman prior to job.

After logging, depending on logging duration and hole conditions, a complete wiper trip to TD (may need to stage into the hole after a long logging job) should be performed.

Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up. Condition the mud – DO NOT POOH until mud properties are within required specifications for running casing. Mud rheology may be thinned to below program specs prior to running casing.

Trip out of hole.

Hold pre-job safety meeting on casing running with all parties involved.

If casing length is greater than riser length, have casing x running string crossover(s) on rig floor. Also have full-opCOMPANYng safety valve for running string in open position and ready to stab, if needed.

Run casing per the program addendum to be issued (threadlock all connections on shoe track).

Make up and stand back the liner hanger/running tool and cementing plug assembly per instructions of cementing and Weatherford service personnel and their respective Field Service Manuals.

• Use a 20' extension pup joint if necessary to permit standing back subassemblies.
• Drift OD of plug launching ball/darts (ensure the landing string has been drifted to the required ID).

Make up and stand back cement head, if not already racked back from previous job.

PU and MU 9 7/8" liner. Recommended MU Torque is 22000 ft-lbs.

9 7/8" Casing String :

• Guide Shoe
• - Jts. 9 7/8" 65.1# T-95 Hydril SLX Pin x SLX Box
• -Autofill Float Collar
• -1 Jts. 9 7/8" 65.1# T-95 Hydril SLX Pin x SLX Box
• -ATC Wiper Plug Indicator Sub
• Approx. 65 Jts. 9 7/8" 65.1# T- 95 Hydril SLX Pin x SLX Box
• Weatherford 9 7/8" Liner Hanger

Run the liner on 5 1/2" 21.90 ppf DP.

• Protech/Centerform composite centralizers will be Installed on each joint on each joint of casing at an interval of 1 per joint from the shoe track to 500' above the top of Galt 70 target.
• Threadlock all connections on shoe track.
• Be sure that lift nubbins are available for handling the casing, if required.
• Apply light coat of Bestolife 2000 thread compound to each connection.
• Apply proper make-up torque to connections.
• Fill the casing while picking up the next joint, ensure the casing is full every 5 joints.
• Place one pup joint with a radioactive tag approximately 300' above each reservoir to flag the sands. Pup joint placement should specified in the program addendum.

Make up liner hanger assembly. LEAVING ROTARY SLIPS SET ON LINER JOINT, pick up approximately 3 feet to verify that the setting tool and all connections are properly torqued up. Once this has been done, pull slips, slack off until PBR sleeve is accessible from the rig floor. Fill the Floating Junk Bonnet with clean water. DO NOT SET SLIPS ON SETTING SLEEVE / PBR. SET DRILL PIPE SLIPS ON SETTING TOOL LIFT SUB. Make up stand of drill pipe to the liner hanger assembly running tool and lower assembly into well. Record liner weight.

Run ATC Diverter Sub 2 stands above liner hanger running tool in the running string.

Continue to run the casing string to TD. Pick up 5' for rat hole. Check the space-out measurements.

• Run liner assembly into well. Install wiper rubber on drill pipe to prevent foreign matter from falling in the well bore.
• Caution should be taken when hanger assembly enters and travels through the BOP stack and wellhead assembly.
• Trip liner in the hole (to casing shoe) monitoring slack off speed and ensuring that assembly is kept full of fluid.
  When the9 7/8” guide shoe reaches the 11 7/8” casing shoe, screw the top drive into the last stand before going out to open hole and get slow pump rates at 15 – 25 – 35 spm through the ATC Diverter Sub. After recording these pressures continue running the liner. Also record liner pick up, slack off, and static weights.
• If Liner rotation is anticipated being required in open hole, calculate maximum drill down torque. Liner thread maximum make-up torque, plus rotating torque established at the casing shoe on last trip out of the hole (Step 15 above) minus 20% safety factor = maximum drill down torque. (Rotate slowly at the shoe prior to entering open hole and record minimum torque required to maintain sustained rotation. This torque to be used as reference.
• Drop ball to convert ATC autofill sub and Davis Lynch float equipment for normal circulation 20 stands from bottom.

When the liner is one stand off bottom, screw the Top Drive in and start pumping slowly to close the ATC Diverter Sub. Keep the pipe moving down hole during this operation. The 1 3/4" ball will be on the seat so pressure up to 600 psi slowly and hold the same for 2 or 3 minutes. Then continue to increase the pump pressure until the ball yields the seat (1500-1800 psi). Note: You will be TIH very slowly when you perform these steps.

After blowing the ball through the seat go back to circulating at 15 spm and record the pump pressure once the returns have stabilized (Do not exceed 800 psi during this operations – the nominal setting pressure of the WCS liner hanger is 1600 psi). The 1 3/4" ball will drop into the ATC Liner Plug System and rest on top of the 3 1/2” ball.

Start washing the last stand to bottom. Wash the liner within 10' of total depth and stop to finish displacing the cuttings out of the liner (Note: This second pressure should be a minimum of 150 psi greater than the previous pump pressure at 15 spm.

Do not attempt to tag actual TD as bottom.

There will be approx. 3' of undergauge hole at TD that creates a false bottom.

The rat hole spacing should be above it.

Calculate amount of slack off required to transfer all the liner weight plus 30,000 lbs. of drill pipe weight onto the liner hanger. Space out drill string to put the Cementing Head a minimum of that distance from the rig floor once hanger is hung off and weight slacked off.

After reaching total depth with the liner, pick up ATC Cement Head and make up same. Start circulating at 30 spm, and record the pump pressure once the returns have stabilized.

Establish pick up and slack off weights. Reciprocate liner while circulating and conditioning mud / hole. (If well conditions permit, and operator has given approval, it is recommended that the pipe be reciprocated during the mud / hole conditioning. Ensure that the reciprocation stroke is not long enough to uncover any formation that must be isolated. This will ensure that inadvertently sticking pipe will not leave that formation uncovered. (It is imperative that the driller understand that the reciprocation stroke be a slow steady movement to prevent harmful pressure surges.)

If hole becomes sticky prior to cementing and/or, hole conditioning is complete, position liner at setting depth (+-5’ off bottom).

After the liner has been displaced, drop the 2 3/8" setting ball and pump same to ATC Diverter sub to land the ball in the ATC diverter sub. Continue to increase pump pressure until the ball yields the seat at 2200 to 2800 psi.

After blowing the ball through the seat the 2 3/8" ball will drop to the ATC Liner Plug System where the ball will land in a yieldable seat. At that time the WCS rep will pressure up in stages to set the hanger (hydraulic hanger set pressure = 1,600 psi). Hold the pressure while the WCS rep works the liner to check and determine if the Hydraulic Hanger is set.

Shut down circulation. With 10-20,000 lb. of drill string weight down on liner hanger, rotate 6-8 torque free turns to the right to release setting tool from the liner. Pick up stretch in pipe plus 5'-10' to see liner weight loss ensuring that setting tool is released from the liner. Note: Ensure that setting tool is not picked up high enough to remove packer actuator sub from the PBR extension. (Double check pick up on slick joint and Floating Junk Bonnet polish nipple)

Set 30,000 lb. of drill string weight back down on liner hanger, to prevent pump out forces of cement job from inadvertently pumping the setting tool out of the liner. Prepare to cement. (Note: Slack off weight will vary from job to job. The Weatherford serviceman will figure his pump out forces on setting tool and set down sufficient weight to overcome those pump out forces)

After verifying the hanger is set, the ATC rep will pressure up to blow the ball seat in the liner running tool. Continue to increase the pressure until the seat yields at 3400 psi and launches the 3 1/2” drop ball from the liner plug system simultaneously.

After launching the 3 1/2” ball go back to circulating a 30 spm and circulate the ball to float collar and activate same.

Circulate and condition the drilling fluid for the upcoming cement job. Recommend not circulating above 30 strokes per minute until the thick mud is above the liner assembly. Circulate bottoms up (minimum 2 x bottoms up from TD to liner top). Boost riser.

Cementing 9 7/8" Casing

Hold pre-job safety meeting on cementing procedures with all parties involved.

Table x (to be included)

Cement Slurry Data

• Use only seawater or drillwater as specified in the cement slurry blend provided by the cementing company lab.
• Test cement lines to 5000 psi.
• Pump required NAF spacer preflush(es) per the cementing program in Section I.
• Pump required cement as detailed in Section I of this program.
• Release the drillpipe dart at the tail of cement. When this dart leaves the cement head we will again see a 1500-2200 psi pressure increase as the dart exits the PLI. Minimum pump rate is 5 bpm at all times.
• Displacement will be with mud. NOTE: IF SYNTHETIC DRILLING FLUIDS ARE BEING USED COMPRESSIBILITY FACTORS, IF APPLICABLE, MUST BE ENTERED INTO DISPLACEMENT FIGURES. CONSULT WITH OPERATOR RIG SUPERINTENDENT AND /OR MUD ENGINEER TO OBTAIN THIS INFORMATION.
• Approximately 5 barrels prior to the drillpipe dart reaching the ATC Diverter Sub slow the pump rate to 5 bpm . The pressure required to yield the seat with the drillpipe dart should range from 1500 - 2000 psi (above the circulating pressure). After yielding the seat the drillpipe dart will latch the liner wiper plug. The pressure required to release the liner wiper plug will range from 1500 - 2000 psi (above the circulating pressure). Record pressure required to shear the plug. Continue with the displacement.
• Approximately 5 barrels prior to the calculated plug displacement to the WPI, slow the pump rate to 5 bbls per minute.
• When the ATC Liner Wiper Plug reaches the WPI, 700 to 1000 psi (above the circulating pressure) should be applied to activate the WPI system. Resume the displacement making appropriate corrections to the total liner displacement if necessary. An additional 150 psi circulating pressure may be seen during this final displacement.
• Approximately 5-10 barrels prior to the calculated plug displacement to the Auto-fill Float Collar, slow the pump rate to 5 bbls per minute
• When the plugs reach the float collar, 1000 psi pressure should be applied to the float collar/wiper plug system. Pump calculated displacement volume and do NOT over displace. DO NOT test casing after bumping plug to avoid a wet shoe if plug leaks
• Release pressure and check to insure that the float valves and/or liner wiper plug is holding.

Set 9 7/8" Liner Top Packer and Test BOPS

Pick up +- feet to release packer actuator sub from the PBR extension. Slack off to contact packer actuator dogs with top of PBR sleeve.

Set down minimum of 40000 lbs. (at liner top) to shear pins and energize the TSP packer (The packer actuator sub has rotational capability. Rotate drill string slowly to the right to change friction points and work weight down to the packer. Up to 100000 lbs. can be used to set packer if necessary.

Close rams, and put a quick test on liner top packer (800 – 1,000 psi). Hold test no longer than 3- 5 minutes if cement was calculated to reach up into lap of liner. (NOTE: Verify test procedures with Operator's rig superintendent. Some operators prefer to reverse out cement prior to putting a test on Liner Top Packer.)

Pick up setting string leaving the end of the setting tool right at the liner top Begin reversing out slowly. Once returns are obtained, pick up slowly until the end of the running tool is approximately 5 feet above the liner top. Increase pump rate and continue to pick up slowly until the end of the running tool is 10-15’ above the liner top. Once sufficient fluid has been reversed out to ensure that all excess cement (Calculated Volume) is out of annulus and either at surface or at least 2,000’ from the end of the setting tool (inside drill pipe), slow pump rate to 1-2 barrels per minute. Slowly slack off setting string inserting the end of slick stinger back into the end of the PBR tie- back extension at least 5-7 ft. Continue circulating for 3-5 minutes and then slowly pick up leaving the slick stinger 5-10 ft above the liner top. Increase pump to desired rate and complete reversing out. Reverse out two drill pipe volumes or until no cement returns are observed. Limit circulating pressure to psi while reversing out to prevent overloading the liner hanger. PRIOR TO JOB VERIFY WITH OPERATOR’S HOUSTON OFFICE THE INTENT TO REVERSE OUT EXCESS CEMENT. VERIFY WITH WEATHERFORD SERVICEMAN LIMITING CIRCULATION PRESSURES.

• Rotate and/or reciprocate drill pipe occasionally, while reversing out to ensure that drill string is free.
• If liner top did not test (if test was performed), and/or attempts to reverse out results in lost returns and/or pressure loss, or, if TSP packer was not set, DO NOT REVERSE OUT CEMENT AT LINER TOP. PULL 5-10 STANDS THEN REVERSE OUT.
• Plan to catch and discard cement-contaminated mud that is reversed to surface.
• MONITOR REMAINING CEMENT PUMPING TIME AS JOB PROGRESSES. IF LESS THAN 1 HOUR OF CEMENT PUMPING TIME REMAINS (INCLUDE ANTICIPATED REVERSE OUT TIME) WHEN LINER WIPER PLUG BUMPS AND PACKER IS SET, POOH WITHOUT REVERSING OUT CEMENT.
• ENSURE THAT SETTING TOOL HAS BEEN PULLED AT LEAST 15 STANDS ABOVE THE LINER TOP WITH NO LESS THAN ½ HOUR OF CEMENT PUMPING TIME REMAINING, IF REVERSING OUT OF EXCESS CEMENT IS NOT COMPLETE.
• VERIFY ITEMS D & E ABOVE WITH OPERATOR’S OFFICE PRIOR TO JOB.

Monitor well conditions. If well is stable, test liner top and/or POOH with drill pipe and liner setting tool as required.

POOH with liner hanger running tool.

Following a minimum WOC time of 6 hrs. with the drillstring above the BOPS, test BOP blind rams and casing as follows:

• Casing / Shear Rams: 250 / 1578 psi
• Pressure must not decline more than 10% in 30 min.

8 1/2" Hole and TD Wireline Logging

xxx' - xxx' TVD RKB (xxx' – xxx' BML)

Drilling 8 1/2" Hole

Hold pre-job safety meeting on handling BHA tools with all parties involved.

L/D 10 5/8" x12 1/4" BHA. P/U 8 1/2" bit and BHA as specified in Section F of this program. PU sufficient 5" DP to extend from the top of the BHA to above the top of the 9 7/8" liner, approx. 3782' / 122 jts. Use 5 1/2" DP above

8 1/2" BHA

• 8 1/2" Bit
• 6 3/4" Autotrak
• 6 3/4" MWD/LWD w/ Mod STB + BCPM
• ORD
• CCN
• Stop Sub
• MWD Filter Sub
• 1 x 6 1/2" DC
• 8 3/8" STB
• 2 x 6 3/4" DC
• XO
• 18 x 5" HWDP
• 5 1/2" Hydraulic Jars
• 11 x 5" HWDP
• 122 x 5" DP
• XO
• 5 1/2" DP

RIH. Test MWD and LWD, if run. TIH and tag the top of cement. Record the TOC depth on the daily drilling report.

Drill cement out of the 9 7/8" casing and drill out the 9 7/8" float shoe.

• Maintain mud properties as specified.
• Before drilling out the shoe, take slow pump rates. Check and record choke and kill line friction pressures. Perform power choke drill.

Drill out 10' of new hole, circulate bottoms up, and pull up to shoe.

Conduct LOT to 15.8 ppg. If LOT is less than an expected, contact the office and prepare to squeeze shoe.

Drill ahead to 8 1/2" hole TD, 14828' TVD / 16110' MD RKB.

Hole Section Mud Properties:

Fluid Type: NAF

MW                PV               YP                ES           Alkalinity      Chlorides       HTHP      LGS

14.4-15.3        20 - 36        12 - 16        >450        ≥5 ppb        250K-275K       <2cc       <6%

• Use 5 1/2" mud pump liners and sufficiently large mesh shaker screens to ensure ability to sweep the hole and handle the increased amount of cuttings at the surface.
• Flow rate: 650 - 800 gpm. Boost riser. Do not exceed the specified flow rates when close to sand reservoirs. Do not perform extended circulation with bit across sands (circulate bottoms up, then pick up above sand to complete circulation).
• WOB: 10 - 20 kips
• RPM: 120 - 150
• ROP: +/-60 ft/hr Use PWD to maintain average ECD 0.5 ppg less than 9 7/8" LOT and ECD surge pressures below 9 7/8" LOT.
• Pump 50 bbl viscous and/or weighted NAF sweeps (FV > 100 sec) every stand for the first 100m and at least every 2 stands thereafter. Occasional sweeps should be pumped to check for cuttings buildup in the hole.
• Take MWD directional survey readings every stand. Ensure MWD is set to operate in the volume range to correspond to the programmed bit hydraulics requirements for this hole section.
• Make wiper trips prior to interval TD only if required by hole conditions.
• Raise MW as hole conditions dictate.
  • NOTE: Take choke and kill line friction pressures any time the MW is raised.
• TD includes sufficient rat hole below the bottom of the last target zone to ensure space for the logging tools. Do not drill beyond planned TD.
• Have LCM available to combat lost returns as specified in Appendix 2.
• If wiper trip is required before reaching interval TD, pump and backream out the first few stands or to the casing shoe, whichever is closest

At section TD, perform wiper trip only if warranted by hole conditions.

Pump hi-vis weighted sweep and circulate hole clean with a minimum of 2 bottoms up.

POOH SLM and prepare to log, if required.

Open Hole Logging

Hold pre-job safety meeting on wireline logging with all parties involved.

Perform logging program as specified in Section 1 of this program.

Perform wiper trips between logging runs as hole conditions dictate.

Permanent Abandonment Procedures for 8 1/2" Hole

Any hydrocarbon bearing zones capable of producing found in the 8 1/2" hole section will be abandoned by placing a balanced cement plug(s) across them.

• RIH with DP and open-ended 3 1/2" tubing stinger to XXXXX' MD.
• Mix and pump XXX sx cement. Set as balanced plug from XXXXX' - XXXXX' MD.

RU and run EZSV on wireline. Set the retainer at XXXXX' MD, XXX' inside the 9 7/8" casing shoe.

RIH with DP and stinger.

RU and pressure test cement lines to 5000 psi.

Sting into EZSV and establish injection rate.

Mix and pump XXX sx cement equal to XXX bbl slurry volume. Squeeze XX bbl below EZSV. Pull stinger from EZSV and spot the remaining XX bbl of slurry on top of the retainer.

Pull slowly from cement plug to XXXXX' and circulate out.

Take on 12.5 ppg WBM.

Displace NAF with WBM from above the cement plug.

Table x :

Cement Slurry Data

Temporary Abandonment Procedures for Well

RIH with DP and 3 1/2 " tubing stinger to XXXXX' or XXX' into the top of the 9 7/8" liner.

RU and pressure test cement lines to 5000 psi.

Mix and pump XXX sx cement equal to XXX bbl slurry volume. Spot slurry as a balanced plug across the top of the liner.

Pull out of the cement plug slowly to XXXXX' MD and circulate out.

POOH to XXXX' or XXX' into the top of the 11 7/8" liner.

WOC and pressure test cement plug to 1000 psi.

RU and pressure test cement lines to 5000 psi.

Mix and pump XXX sx cement equal to XXX bbl slurry volume. Spot slurry as a balanced plug across the top of the liner.

Pull out of the cement plug slowly to XXXX' MD and circulate out.

POOH to XXXX' or XXX' into the top of the 16" liner.

WOC and pressure test cement plug to 1000 psi.

RU and pressure test cement lines to 5000 psi.

Mix and pump XXX sx cement equal to XXX bbl slurry volume. Spot slurry as a balanced plug across the top of the liner.

Pull out of the cement plug slowly to XXXX' MD and circulate out.

WOC, then RIH and weight test top of cement plug with 10K WOB.

POOH and LD tubing stinger.

Displace riser with seawater.

Disconnect from wellhead and winch rig to safe zone.

Pull riser and BOPs. Run corrosion cap and inject corrosion inhibitor with ROV. Conduct sight clearance survey.

Table x (to be included)

Cement Slurry Data

Rig Demobilization and Move Off of Location

Backload well tangibles and materials. Rig down communications.

While holding rig on station, pull the remaining anchors. The rig will be prepared for tight tow as the AHV will begins pulling the last anchor.

Move rig from the XXX Location.

BOP & Casing Test Pressures

MD Interval - Csg Size        - MAWP@WH (psi) - PT Csg (Plan MW)            - BOP LPT      - BOP PT / Ann PT    - PT Hgr Seal Assy)
Stump Test                                                                                              250               15,000 / 7,000
xxx' – xxx'      36"                  NA                       NA                                   NA                 NA                         NA

xxx' – xxx'      20"                  NA                       NA                                   NA                 NA                         NA

xxx' – xxx'      16”                  2445                     3970 w/ 10.0 ppg              250                 5,000 / 3,500          NA

xxx' – xxx'      13-5/8’’           2603                      3772 w/ 10.8 ppg             250                 5,000 / 3,500           NA

xxx' – xxx'      11-7/8’’           4480                      4683 w/ 12.0 ppg             250                 7,500 / 5,000           5000

xxx' – xxx'      9-7/8"            5966                      3035 w/ 13.0 ppg              250                7,500 / 5,000            NA

xxx' – xxx'      NA                 5815                     1578 w/ 14.4 ppg               250                 7,500 / 5,000           NA

Note:

• Test pressures are based with planned MW listed above. Re-calculate test pressure if MW in the hole is different to give same ppge at shoe.
• Casing test will be performed against the BSR’S

Drills and Tests

• Test BOPE per COMPANY and DODI’s requirements.
• Pit Drills will be performed and recorded per COMPANY and DODI’s requirements.
• Abandon Rig and Fire Drills will be performed per COMPANY and DODI’s requirements.