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As usual, winter — or the slow season — is the time most drillers take the time to maintain their equipment in order to get ready for the peak season. One of the main parts that usually needs attention is the mud pump. Sometimes, it is just a set of swabs to bring it up to snuff, but often, tearing it down and inspecting the parts may reveal that other things need attention. For instance, liners. I can usually run three sets of swabs before it is time to change the liner. New liners and swabs last a good long time. The second set of swabs lasts less, and by the time you put in your third set of swabs, it’s time to order new liners. Probably rods too. It’s not always necessary to change pistons when you change swabs. Sometimes just the rubber needs to be changed, saving money. How do you tell? There is a small groove around the outside of the piston. As it wears, the groove will disappear and it’s time for a new piston.

The wear groove on a piston can be a good indicator of the general health of your pump. If the wear is pretty even all around, chances are the pump is in pretty good shape. But if you see wear on one side only, that is a clue to dig deeper. Uneven wear is a sign that the rods are not stroking at the exact angle that they were designed to, which is parallel to the liner. So, it’s time to look at the gear end. Or as some folks call it, “the expensive end.”

The wear groove on a piston can be a good indicator of the general health of your pump. If the wear is pretty even all around, chances are the pump is in pretty good shape. But if you see wear on one side only, that is a clue to dig deeper.

After you get the cover off the gear end, the first thing to look at will be the oil. It needs to be fairly clean, with no drill mud in it. Also look for metal. Some brass is to be expected, but if you put a magnet in the oil and come back later and it has more than a little metal on it, it gets more serious. The brass in the big end of the connecting rod is a wearable part. It is made to be replaced at intervals — usually years. The most common source of metal is from the bull and pinion gears. They transmit the power to the mud. If you look at the pinion gear closely, you will find that it wears faster than the bull gear. This is for two reasons. First, it is at the top of the pump and may not receive adequate lubrication. The second reason is wear. All the teeth on both the bull and pinion gears receive the same amount of wear, but the bull gear has many more teeth to spread the wear. That is why, with a well maintained pump, the bull gear will outlast the pinion gear three, four or even five times. Pinion gears aren’t too expensive and are fairly easy to change.

If the gears look OK and there are no obvious bearing problems, the next parts to look at are the crank journals; they ride in the brass at the big end of the rod and take plenty of abuse. This is where it gets interesting. To repair or replace is the big question. Replacement is pretty expensive and you may have to wait a while. Repairs are more my style because I know some excellent machinists and can tell them exactly what I need done. If your journals are deeply scored, you will have to turn the crank. It takes a pretty special machine to do this, but one of my friends has one and is a master with it. The procedure is to turn down the journals and press a steel sleeve over them, bringing them up to factory new specs.

This process is fairly straightforward machine work, but over the years, I have discovered a trick that will bring a rebuild up to “better than new.” When you tear a pump down, did you ever notice that there is about 1-inch of liner on each end that has no wear? This is because the swab never gets to it. If it has wear closer to one end than the other, your rods are out of adjustment. The trick is to offset grind the journals. I usually offset mine about ¼-inch. This gives me a ½-inch increase in the stroke without weakening the gear end. This turns a 5x6 pump into a 5½x6 pump. More fluid equals better holes. I adjust the rods to the right length to keep from running out the end of the liner, and enjoy the benefits.

Other than age, the problem I have seen with journal wear is improper lubrication. Smaller pumps rely on splash lubrication. This means that as the crank strokes, the rods pick up oil and it lubricates the crank journals. If your gear end is full of drill mud due to bad packing, it’s going to eat your pump. If the oil is clean, but still shows crank wear, you need to look at the oil you are using.

Oil that is too thick will not be very well picked up and won’t find its way into the oil holes in the brass to lubricate the journals. I’ve seen drillers that, when their pump starts knocking, they switch to a heavier weight oil. This actually makes the problem worse. In my experience, factory specified gear end oil is designed for warmer climates. As you move north, it needs to be lighter to do its job. Several drillers I know in the Northern Tier and Canada run 30 weight in their pumps. In Georgia, I run 40W90. Seems to work well.

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

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

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.).

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.

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.

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.

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.

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.

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.

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:

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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).

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).

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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.

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).

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.

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.

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.

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.

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.

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.

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.

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.)

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)

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.

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.

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.

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

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.

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.

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.

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.

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).

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.

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 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.

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.

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.

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.

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.

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.

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.

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.)

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)

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.

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.

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.

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

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.

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.

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.

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

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).

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.

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.

Chrome-Iron Liners . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6

Zirconia-Ceramic Liners . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7

Mud-Pump Gear Sets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13

Service and Support . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16

Kverneland, Hege, Kyllingstad, Åge, and Magne Moe. "Development and Performance Testing of the Hex Mud Pump." Paper presented at the SPE/IADC Drilling Conference, Amsterdam, Netherlands, February 2003. doi: https://doi.org/10.2118/79831-MS

Technical Specification Pre-Shipment And Storage PS-4030 02 Preservation For New-Build NOV Triplex Mud Pumps

Product Information Bulletin Triplex Mud Pumps Power 01-05-01-MP 06 End Lubrication Oil Additive and wear-in Period

Procedure The Use of and Application of Safety Wire for ASP00019 A Secondary Retention Design Specification Design Torque Standard DS00008 F General Lubrication Bulletin General Lubrication Bulletin CE-538E 06 for CE Drilling Equipment

RIG/PLANT REFERENCE REFERENCE DESCRIPTION Triplex Mud PumpADDITIONAL CODE SDRL CODE TOTAL PGS This document contains proprietary and confidential information National Oilwell Varco which belongs to National-Oilwell Varco, L.P., its affiliates orREMARKS subsidiaries (all collectively referred to hereinafter as "NOV"). It is loaned for limited purposes only and remains the property of NOV. 11000 Corporate Centre Drive Reproduction, in whole or in part, or use of this design or Suite 200MAIN TAG NUMBER DISCIPLINE distribution of this information to others is not permitted without the Houston, Texas 77041 express written consent of NOV. This document is to be returned to NOV upon request and in any event upon completion of the use for U.S.A.CLIENT PO NUMBER which it was loaned. This document and the information contained and represented herein is the copyrighted property of NOV. Phone: +1-281-854-0400 National Oilwell Varco Fax: +1-281-854-0607CLIENT DOCUMENT NUMBER DOCUMENT NUMBER REV

02 12.09.2012 For Information RLP BTS GDH 1 15.08.2006 For Information GDH GDH GDH 0 07.05.1990 For Information GDH GDH GDH Rev Date (dd.mm.yyyy) Reason for issue Prepared Checked Approved

1 SCOPE.............................................................................................................................. 42 MANUFACTURING PLANT PRESERVATION PRIOR TO PAINT .................................. 43 MANUFACTURING PLANT PRESERVATION AFTER PAINT ........................................ 54 STORAGE AT MANUFACTURING PLANT OR FINAL DESTINATION .......................... 65 STORAGE PREPARATIONS FOR MAIN DRIVE MOTORS. ........................................... 66 PRESERVATION PROCEDURE WHEN STORAGE EXCEEDS SIX (6) MONTHS OFINITIAL PRESERVATION. .......................................................................................................... 67 START-UP AFTER STORAGE ........................................................................................ 78 CONTACT DETAILS FOR NOTED CORROSION PREVENTATIVE MATERIALS ......... 79 EXHIBIT 1 ......................................................................................................................... 810 EXHIBIT 2 ......................................................................................................................... 9

This specification covers the preservation and storage procedure for shipment of new-build NOV Triplex Mud Pumps shipped from the manufacturing plant.

This specification is intended to provide preservation of new-build NOV Triplex Mud Pumps for six (6) months from the shipment of the mud pump from the manufacturing facility. If a pump is to be stored for a period of time exceeding six (6) months, additional precautions should be taken as outlined in this specification.

National Oilwell Varco recommends that all pumps are inspected for any signs of corrosion and for proper preservation at a minimum every three (3) months for pumps stored outside and every six (6) months for pumps stored indoors.

Drain all water and clean out liner wash tank. Remove drain plug in bottom of liner wash pump and drain water then reinstall plug. Remove discharge flange from liner wash pump and pour one (1) pint of inhibiting oil-based concentrate (Cortec VpCI 329 Vapor Corrosion Inhibiting oil-based concentrate or equivalent) into liner wash pump. Rotate two (2) revolutions by hand to distribute the product. Re-install discharge flange.

Drain all oil from pump power end sump and remove crosshead covers and inspection covers. Clean out oil sump as per National Oilwell PS-3081 (Mud Pump Cleanliness). Spray all internal machined parts of power end and crosshead area with inhibiting oil-based concentrate (Cortec VpCI 329 Vapor Corrosion Inhibiting oil-based concentrate or equivalent). Rotate pump turn and re-spray. Pour quantity of inhibiting oil-based concentrate specified in the table below into power end sump.

Mud Pump Models Quantity of Inhibitor 14P, FC 2200 5 Gallons 12P, 10P, HD or A1700/1400PT, FB/FC/FD 1600, FB 1300 3 Gallons 9P, 8P, B or A850-1100PT, F/FD 1000, F 800 2 Gallons 7P, A600PT, FD 500 1 Gallon

For pumps equipped with chain drives, spray internal machined parts inside chain cases with inhibiting oil-based concentrate (Cortec VpCI 329 Vapor Corrosion Inhibiting oil based concentrate or equivalent).

www.nov.com Document number PS-4030 Revision 02 Page 5

Remove fluid end valve covers, seals, valves springs and seats and treat internal cavities of fluid ends, discharge manifold, discharge strainer block and suction manifold with rust preventative (CRC SP400 or equivalent). Coat threads with anti-seize (KOPR KOTE 10002 or equivalent) and coat bottom side of valve cover with rust preventative. Reinstall seals and fluid end valves covers hand tight. Customer liners, pistons, piston rods, valves, seats, springs and liner retention parts are not used for plant testing. These expendables are checked for preservation when packed and then shipped with the loose parts.

Remove breather and pack with loose parts for later shipment with pump. Seal breather hole with a greased solid plug. Affix a warning label near the breather opening (see Exhibit 1).

Seal all other pipe work (air, water, and electrical) with plastic caps of the correct size and style. Electrical J-boxes are to be encased in protective plastic wrap. Place two (2) one- pound bags of desiccant inside each J-box before sealing with tape. Wrap pressure gauges with bubble paper and plastic.

Spray all machined unpainted loose parts and expendables to be shipped with pump with rust preventative (CRC SP400 or equivalent). All parts will be wrapped or boxed to prevent damage.

Affix one (1) warning label (see Exhibit 2) to the power end pump cover and one (1) warning label on the fluid end assembly of the pump. Affix warning labels on each loose part container. In cases where the equipment will be boxed at an offsite export packer, a sufficient number of warning labels will be supplied with the shipment.

www.nov.com Document number PS-4030 Revision 02 Page 6

Indoor storage is preferred whenever possible; but if outside storage is required, ensure pump is stored away from salt water spray, sand blast or other adverse conditions. It is highly recommended that ship loose parts be stored indoors to eliminate conditions that promote condensation and direct sources of moisture.

For storage preparations for main drive motors, National Oilwell Varco recommends that the original manufacturers instructions be followed. If space heaters are supplied, the J- box plastic wrap must be removed and the heaters should be connected throughout the complete storage period.

Note: It is recommended that inspections be carried out on six (6) month cycles when pumps are in indoors and three (3) month cycles when stored outside.

Any pump that has