Weatherford MPD Webcast - Offshore - Proven Accepted Expected


an adaptive drilling process used to more precisely control the annular pressure profile throughout the wellbore.


(1) to ascertain the downhole pressure environment limits (2) to manage the annular hydraulic pressure profile accordingly


KEY COMPONENTS



diverts the annular flow of a well being drilled.


An RCD serves as a barrier between the well and rig floor at various amounts of annular pressure.

The industry-approved standard for an RCD is API 16RCD.


Detection Control


PRESSURIZED MUD-CAP DRILLING (PMCD) enables high ROP, less flat time and lower-cost drilling in extreme-loss situations.

CONSTANT BOTTOMHOLE PRESSURE (CBHP) reduces NPT and enables fewer and deeper casing strings when drilling windows are narrow or relatively unknown.

DUAL GRADIENT DRILLING (DGD) enables total well depth in the right hole size in deep well and deepwater drilling. Hydraulically speaking, DGD tricks the well into thinking the rig is closer.

RETURNS-FLOW-CONTROL (HSE) reduces risk to personnel and the environment from drilling fluids and well control incidents.

The goal of MPD is to control the pressure profile in a way that eliminates many of the drilling and wellbore stability issues that are inherent in conventional drilling methodologies.


MPD Systems also provide advanced flow detection (AFD) and consequently, riser gas mitigation (RGM) advantages.

A rotating control device (RCD) creates a closed, pressurizable drilling system.

The RCD effectively redirects flow coming out of the well to automated MPD detection & control manifolds.

The MPD detection manifolds high-resolution mass flow meter increases sensitivity and reaction time to kicks, losses and other events.


SOURCE:

PMCD is a variant of MPD that involves drilling without any returns to surface.


An annulus fluid column, assisted by surface pressure exerted with a rotating control device (RCD), is maintained above a formation able to accept fluid/cuttings.

A sacrificial fluid with cuttings is accepted by the loss circulation zone.

Useful for cases of severe loss circulation that preclude the use of conventional drilling techniques.

SOURCE:


Bo

tto

m H

ole

Pre

ssu

re

Time

Fracture Pressure

Reservoir Pressure

Large Drilling Window


Constant Bottomhole Pressure

Bo

tto

m H

ole

Pre

ssu

re

Time

Fracture Pressure

Reservoir Pressure

CBHP enables navigation through narrow mud weight windows.

Narrow Mud Weight Window


Subsea RCD for Dual Gradient A key component in one of the dual gradient drilling systems is the industry's first commercially available subsea rotating device (SRD), which diverts drilling fluids to establish a dual gradient environment.


MPD: DP Drillship


Rapidly and accurately applied and managed backpressure to determine the actual pressure profile of the wells

Allowed for immediate detection and control of kicks PMCD mode allowed the deepwater well to be drilled safely

to its targeted depth

Well was subsequently logged safely through the RCD system, despite total loss of circulation

Makassar Strait, Indonesia Water Depth ~6,000 ft

MPD is commonly used to manage geo-pressure environment uncertainties and associated risks in wildcat wells.


Offshore Cameroon High pressure Depth of gas influx 10,463 ft (3,189 m) Influx size 3.2 bbl, 24% maximum gas reading Hole Size 8 1/2 in.

MPD is commonly used to manage geo-pressure environment uncertainties and associated risks in wildcat wells.

Navigated and drilled through a tight pressure window

Mitigated potential gas influxes caused by the changing pressure regimes and reduced nonproductive time (NPT) through early kick and loss detection

Enhanced overall operational safety by gaining control of bottomhole events

Enabled circulation of the influx out of the system at drilling

flow rate (used only 1 hour of rig time) while balancing the well, which saved time compared to slower, conventional methods


Southwest Gulf of Mexico Formations Medium Cretaceous, Lower Tertiary

Using the CBHP variant of MPD, drilled the well with no loss of circulation in a shorter time frame than initially allotted

Drilling time was reduced from 30 days to 5 days (83 percent) and mud savings exceeded US $1 million

Applied MPD engineering, including continuous hydraulic stimulation, and increased drilling efficiency by mitigating drilling hazards

MPD enables drilling of successful wells in areas that have challenged conventional drilling methods.


Offshore Kalimantan, Indonesia Bottomhole Pressure 12,000 psi Temperature 175 degrees C

Drilled an offshore exploration well with HP/HT and narrow mud weight window characteristics to the deepest depth possible

MPD was used to apply annular back pressure while drilling,

making connections and tripping

Allowed dynamic testing of fracture pressures and rapid changes of bottomhole pressures to simulate higher mud weights and detect changes in background gas levels

MPD enabled safe circulation of gas-cut mud and dynamic LCM squeezes in zones where fluid losses occurred

MPD enables drilling of successful wells in areas that have challenged conventional drilling methods.


Offshore Peninsular Malaysia

MPD enables development drilling that is production-friendly and equipped to handle numerous contingencies.

Using CBHP-MPD, safely drilled two subsea development wells using a statically and underbalanced drilling fluid and maintained well control integrity

Automated MPD system was used to drill with fluid densities of 12.7 ppg to a target depth of 1,869 m (6,132 feet) and provided early kick and loss detection

Narrow drilling mud weight window was managed properly by utilizing CBHP-MPD during drill string connections

Reduced NPT spent weighing mud by instead adjusting backpressure and verifying the geo-pressure environment


Offshore Oman Well Type Deviated Formations Illam, Laffan, Mishrif, Khatiyah, and Maddud limestones

MPD enables development drilling that is production-friendly and equipped to handle numerous contingencies.

Reached TD in three wells by mitigating conventional drilling NPT issues such as lost circulation, differential sticking, and well-control incidents

MPD technology enabled the use of lighter mud weights,

which reduced the requirements for fluid loss control

MPD system determined precise formation pressure limits through dynamic pore-pressure tests and formation integrity tests

Reduced NPT through early kick and loss detection and increased ROP


MPD allows safe and efficient re-entry of abandoned wells with well integrity issues.

Safely re-entered and properly abandoned an offshore development well in shallow water to address leaks from previous isolation methods deployed

MPD helped cap the well and immediately detected an influx of gas during re-entry operations once the isolation plugs were drilled out

Enhanced surface flow monitoring allowed for proper risk mitigation and ensured that immediate action could be taken to secure the well, if and when required


Pre-Salt


Use of MPD to address severe circulation losses provides multiple efficiency and safety benefits over conventional methods.

PMCD has been used successfully on all types of offshore rigs to continue drilling offshore wells in total-loss zones that would otherwise have been extremely difficult to drill through

RCDs are used by offshore drilling-enabled operating companies to increase the safety of future drilling operations, especially when total circulation losses occur

MPD technology effectively reduces nonproductive time when drilling offshore

In PMCD mode, the ability to pump seawater down the drill string as a substitute for drilling fluid helps reduce mud costs. Cuttings go to large fractures in the formation

Offshore Asia Pacific Region Locations (Malaysia, Indonesia, Vietnam, Philippines, Thailand, etc.) Well Type Various Formations Fractured limestone and Carbonate / basement


When lost circulation (720 bbl/hr) was encountered, the MPD pressurized mud-cap technique was initiated, allowing drilling to continue to TD

Minimized downtime resulting from lost circulation; no rig time was wasted mixing and spotting lost-circulation material

No H2S was brought to the surface during drilling

The average section rate of penetration increased five times over that of the previous well in the block

Offshore Angola Well Type Oil producer with gas cap, 1 to 2% H2S Formations Middle Pinda, highly fractured formation 2015 Weatherford. All rights reserved.


Minimized NPT from losses and kicks by managing annular pressure during drilling to ascertain operational limits and stay within the pressure window

MPD enabled the operator to switch from CBHP to PMCD mode if fluid losses into the formation became unsustainable

Reduced NPT related to downhole problems to one day (compared to an average of ten days for each of the three previously-drilled wells in the field)

Fluid losses were minimized to 290 bbl of synthetic oil-based mud, compared to previous losses of up to 4,000 bbl

Offshore India Well Type Vertical high-pressure, high-temperature well Formations Fractured limestone and carbonate late Oligocene Depth 7,113 to 14,193 ft (2,168 to 4,326 m) Hole Size 8-1/2 and 12-1/4 in. 2015 Weatherford. All rights reserved.

Use of MPD for navigating narrow mud weight windows and early kick detection enables drilling of HPHT wells in clastic reservoirs.

Safely drilled an 8 1/2-in. section to TD within a narrow 0.4-lb/gal (0.05 kg/L) drilling window under extreme pressure and temperature conditions

Maintained an overbalanced wellbore and controlled ballooning / breathing events by evaluating pore pressure and detecting kicks

MPD saved an estimated 10 rig days valued at $7.5 million, while reducing risk and enhancing safety

Controlling gas influxes and precisely weighting up the mud system saved time compared to a conventional system

Offshore Norway Well Type Offshore, exploratory, HPHT Production Hole Size 8-1/2 in. (216 mm) Total Depth 19,465 ft (5,933 m)


Use of MPD addresses uncertainties and risks associated with pre-salt formations.

Re-entered a plugged, cemented, and abandoned well in 6,562 ft (2,000 m) of water in the deepwater pre-salt area of Brazil

Previous drilling was terminated when the operator encountered a severe fluid loss zone that consumed 600 bbl/hr (95 m3/hr) that led to plugging and abandonment

MPD was used until total losses experienced. At 16,552 ft (5,045 m), the team switched to PMCD mode

Reached the targeted production zone in PMCD mode at an estimated depth of 16,781 ft (5,115 m) and enabled well completion

Brazil, Santos Basin Well Type Deepwater, vertical Reason For Abandonment Massive fluid losses while drilling


Documents

Weatherford MPD Webcast - Offshore - Proven Accepted Expected