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JumpStart™ Well Cleanout ServiceHighly reliable, safe solution

The JumpStart Well Cleanout Service offers operators a range of service and support options to ensure a highly reliable, cost-saving well cleanout solution. This patent-pending method of deploying a fully retrievable through-tubing ESP system reduces flowback and cleanout rig time by 50 percent in vertical, deviated, horizontal and multilateral wells. An alternative to conventional flowback and cleanup operations, the JumpStart service is licensed to AccessESP by Saudi Aramco Technologies Company for worldwide deployment in onshore and offshore wells.

Enhancing flowback and cleanup operations

Effective well cleanup following completion is an essential step in preparing the reservoir for production and for ensuring the integrity of fluids entering the gathering system. In some high-value, challenging wells, the flowback and cleanup operation can be risky and time consuming since it requiresa complicated coiled tubing (CT) and nitrogen lift process to remove debris and reduce the hydrostatic head in the wellbore. The Saudi Arabian Oil Company (Aramco) set out to develop a safer, less costly alternative method that would meet four objectives:

• Minimize risk by dramatically reducing the amount of heavy equipment and personnel at the wellsite

• Establish a new technical limit for well cleanup operations with less rig time, fewer execution failures and reduced operating cost

• Eliminate the use of high-pressure gas and chemicals to ensure zero environmental impact

• Cut greenhouse gas emissions.

The AccessESP GoRigless™ ESP System was selected to meet these objectives by cleaning out the wellbore without coiled tubing or nitrogen lift. By temporarily installing a slickline-retrievable electric submersible pump in the well, heavyweight kill fluids can be removed in half the time required to perform a coiled tubing–deployed nitrogen lift operation, enabling

natural flow to begin several days to a few weeks earlier.

Documented savings from using the GoRigless ESP technology for wellbore cleanout and flowback operations have averaged US$1.1 million for offshore deviated and horizontal wells, US$3 million for multilateral wells and US$0.8 million for land wells.

Proven operational procedure

The GoRigless ESP System used in the well cleanout procedure has been qualified, tested and proven in offshore and land wells in Alaska, Angola, Brunei and Saudi Arabia. The equipment has achieved a highly reliable track record for new completions and for gas lift well conversions to ESP. It is designed for 4.5-in. or larger production tubing.

The procedure begins with the GoRigless

JumpStart Well Cleanout Service

Permanent Completion Assembly installed with tubing. The setting depth is determined for each well based on unloading requirements. The Permanent Completion Assembly serves as a docking station for the GoRigless Retrievable Assembly, a slickline-deployed downhole pump and permanent magnet motor. A unique dry-mate connector mounted on a

plug arm makes the electrical connection between the cable run outside the casing and the motor run inside the tubing.

A slickline unit is deployed for six to eight hours to make four runs to install the Retrievable Assembly. Once the ESP system is ready to run, the well fluid can be lifted directly to the surface at very high

10 to 20 days 5 to 10 days

CT N2 Injection Rigless ESP

10 to 20 days 5 to 10 days

CT N2 Injection Rigless ESP

CT N2 Injection (left) vs deploying a rigless ESP pumpout solution (right). Saudi Aramco and AccessESP jointly developed a reliable method to deploy an ESP to remove kill fluids without CT or N2 injection.

A comparison of the typical CT nitrogen-lifted well cleanup with a GoRigless ESP System cleanout reveals multiple, significant benefits.

Typical CT nitrogen–lifted cleanup

• Much simpler

• Low risk

• 4 to 5 lifts

• 3 connections

• High slickline availability

• Low slickline day rate

• > 6 years failure free

• Much less HSE risk

JumpStart well cleanup with GoRigless ESP System

• Lower CAPEX

• Lower OPEX

• Accelerated production

• High ROI, payback

• Reuse of equipment or leave in well for lift

• 3000- to 6000-bbl/d pumpoff rate

• Very complex

• High-risk operations

• >25 lifts

• ~20 connections

• Uncertain CT availability

• High CT day rate

• High-pressure operations

• 300- to 600-bbl/d pumpoff rate

JumpStart Well Cleanout Service

rates — 3,000 to 6,000 bbl/d. Note the pumpoff rate for coiled tubing nitrogen lift is typically 300 to 600 bbl/d.

At the conclusion of the cleanup, the Retrievable Assembly is quickly removed with slickline, and

Packer

Seals/protectors

PermanentMagnet Motor

(PMM)

Sensor Pump

Packoff

Tubingstop

Check valve

Plug armAnnularconnection

port

1 2 3 4

PermanentCompletionAssembly

RetrievableAssembly

The Permanent Completion Assembly is installed with the production tubing to offer life-of-well flexibility for well cleanup and optimized drawdown. The Retrievable Assembly can be removed and redeployed through tubing with four slickline runs. The ability to selectively change out the entire assembly or the pump alone without pulling tubing saves millions in workover costs.

AccessESP PMM Motor Conventional ESP Induction Motor

Power Length (ft) Weight (lbm) Length (ft) Weight (lbm)

A375 3.75 in. OD

4.5/5.5-in. tubing

130 hp 9.1 235 51.2 1,980

250 hp 16.4 424 84.0 3,400

400 hp 23.7 614 Not Available Not Available

the well is ready to flow to the production facility without removing tubing. The Permanent Assembly and cable remain in the well to allow an ESP to be redocked in the future to boost production without an expensive heavy intervention with a rig.

JumpStart Well Cleanout Service

A375

Tubing Stop

OD (in.) 3.72

Length (ft) 1.57

Tubing Packoff

OD (in.) 3.72

Length (ft) 2.83

Standing Valve

OD (in.) 3.72

Length (ft) 1.32

Stinger

OD (in.) 3.72

Length (ft) 0.88

PBR

OD (in.) 3.72

Length (ft) 2.10

Pump and Intake (depending on application)

OD (typical, in.) 3.75

Length (ft)1,2 varies

Seal (Protector) (depending on application)

OD (in.) 3.38 or 3.75

Length (typical, ft)1 6.50

Permanent Magnet Motor (PMM)

OD (in.) 3.75

Horsepower 130 to 400

Length (ft)1 hp dependent

Gauge

OD (in.) 3.75

Length (ft) 2.50

Plug Arm Assembly

OD (in.) 3.75

Length (ft) 11.83

Motor Guide

OD (in.) 3.75

Length (ft) 0.50

1 – Depends on well application2 – When casing sizes permit, larger tubing can be

run allowing larger OD pumps, hence flow rate (estimated maximum range: 7,500 bbl/d with 4.5-in. tubing, 12,000 bbl/d with 5.5-in. tubing, 30,000 bbl/d with 7-in. tubing)

Notes

Overcoming inertia to adopt game-changing technology

AccessESP offers operators critical support to reliably deploy the GoRigless ESP system to accelerate time to first oil while reducing risk, well cleanup rig time, operating cost and greenhouse gas emissions. The innovative JumpStart Well Cleanout Service allows relevant drilling, completion, production and reservoir stakeholders to collaborate with the AccessESP team to ensure effective cleanout and flowback at the lowest possible cost.

The AccessESP management team firmly believes that real collaboration in the well cleanout design and planning process ensures a successful operation with the greatest bottom-line value.

The cost saving gained by reducing rig time and eliminating coiled tubing and nitrogen pumping is significant. The JumpStart process also lowers transportation costs, decreases heavy lifts, reduces the number of personnel on board, and frees deck and bed space previously required for CT operations. In addition, the volume of gas to be handled at the surface is considerably less because completion fluid can be pumped directly to the tanks with no gas to separate until wellbore fluids begin to arrive, which provides a measurable improvement in safety.

CT not required N2 not

required

JumpStart

JumpStart Well Cleanout Service

A375

Retrievable Assembly

Pump size (nominal) 3.75 in.

Conveyance options Slickline, Braided Line, Coiled Tubing, Tractor

Typical system length1 85 ft

Typical system weight1 1,900 lbm

Typical deployment length2 40 ft

Typical deployment weight2 1,000 lbm

Environmental Specifications

Maximum winding operating temperature 400°F

Maximum work ambient temperature 350°F

Pressure 7,500 psi

Performance

Maximum horsepower 400 hp

Maximum flow3,4 7,500 bbl/d

Annular Connection Port (ACP)

Minimum tubing size 4.5 in.

Minimum casing size 7 in.

Length 8.5 ft

Maximum OD 5.85 in.

Throughbore diameter 3.83 in.

Burst pressure with isolation sleeve5 10,000 psi

Collapse pressure with isolation sleeve5 6,000 psi

In-Line Connection Port (ICP)

Minimum tubing size 4.5 in.

Minimum casing size 9.625 in.

Length 14 ft

Maximum OD 7.63 in.

Throughbore diameter 3.83 in.

Burst pressure with isolation sleeve5 7,000 psi

Collapse pressure with isolation sleeve5 7,000 psiAnnular

Connection Port (ACP)

In-line Connection Port (ICP)

1 – Depends on well application2 – Excludes running tools (above length, estimated typical per run section)3 – Based on ESP pump design4 – When casing sizes permit, larger tubing can be run allowing larger OD pumps, hence flow

rate (estimated maximum range: 7,500 bbl/d with 4.5-in. tubing, 12,000 bbl/d with 5.5-in. tubing, 30,000 bbl/d with 7-in. tubing)

5 – Based on 80-kpsi material; higher ratings available upon request

Notes