Smart Wells

1
Smart Wells Status on the Norwegian Continental
Shelf
P. Keül-TotalFinaElf Exploration Norge S.
Erlandsen- Norsk Hydro Ø. Tesaker-Statoil
2
Smart Wells

• Definition
• Purpose
• Available systems
• Review of installations on NCS

3
SMART WELL

• Well with multiple zones completion and one
  production tubing
• Sensors allowing to monitor parameters specific
  for each zone
• pressure, temperature, flow rate, water cut, etc.
• Zone control equipment with a topside unit to
  remote operate the control equipment for
  production and injection optimalisation

4
Example of Smart well completion- SCRAMS
5
DIACS (Downhole instrumentation and control
system).Operation and management

• Reservoir management phase well potential
  higher than design rate.
• Balance voidage to delay water and gas
  breakthrough
• Produce oil difficult to access
• Production optimisation phase gas and water
  limitations occur
• Choke back high GOR/water cut intervals to
  optimise production

Reservoirmanagementphase
6
Smart well Systems. Major vendors
7
Smart well Systems. Others.
8
Experience With DIACS on Oseberg.
Oseberg is a mature field with gas capacity
constraints.The Ness reservoir consists of
sandbodies with varying communication DIACS used
to optimise production by choking high GOR
zones. Status on SCRAMS May 98. Prod B-30B. 1
zone. Operating. Lost position indicator. Aug 98.
Prod B-21B. 4 zones. Lost com to zones 2-4. Nov
98. Prod. B-41A. 4 zones. No com to zone 2-4. Aug
99. Prod. B-29B. 3 zones. Working Reliability of
hydraulic/electric system not satisfactory.
Decision to test complete hydraulic system,
Camco/Schlumberger May 2000. B-38. 3 zones.
Working. 1 zone stuck.May 2001. C-19. 3 zones.
Working. Pressure sensors failed.
9
Smart well completion in Oseberg 30/9-B-21
ALL DEPTHS REFER TO RKB MD
Cellardeck 30m
DHSV control line
Seabed at 168 m
5½ TRSCSSV at 255 m MD
30 csg shoe at 238 m MD
4 x SCRAMS control lines 2 x electric, 2 x
hydraulic
18 5/8 csg
7 26 tubing
13 3/8 csg shoe
9 5/8 HF packer
Top 7 liner
4 tubing
7 x 5½ X-over
HF packer 7 x 3½
SCRAMS ICV 5½
5½ x 4 X-over
9 5/8 csg
3½ ICV
HF Packer 7 x 3½
10
(No Transcript)
11
Snorre B development
Snorre B is a subsea development with WI and
downdip WAG asrecovery mechanism.By penetrating
the reservoir with horizontal or highly deviated
wells, the number of wells was reduced to 10
injectors and 17 producers. The development
concept requires zonal control. All injectorsand
7 of the producers to be equipped with DIACS.
SCRAMS hasbeen tested out at Snorre (P-18) and
at Rogaland Research. Testsnot conclusive. NH is
testing Baker as an alternative. 3 wells have
been pre-drilled at Snorre B, but no DIACS
installed.Next well (WI) to be equipped with
SCRAMS. Choice of system for the remaining wells
pending.
12
(No Transcript)
13
(No Transcript)
14
DIACS Other experience

• Sleipner Øst
• 4 zones SCRAMS in gas producer/injector. SCRAMS
  working, but tubing has been eroded. Not possible
  to isolate upper perforations.
• Gullfaks
• 4 zones SCRAMS in OP. Working. P,T gauges, but
  not online monitoring.
• Norne
• 1 installation of Camco/Schlumberger gas lift
  valves. Working.
• Troll
• 7 installations of Camco/Schlumberger gas lift
  valves. 6 working.

15
DIACS Other experience (cont.)

• Smørbukk
• Production strategy to prioritise low GOR wells.
  Aim to control flow to or from up to 5 reservoir
  zones. Potential proved, but reservoir conditions
  indicate mechanical solution.
• Statfjord
• 4 zones DIGIHYD system in OP. Not working. Will
  be operated with coiled tubing.
• Oseberg East
• Tubing leakage in injector. Evaluation to pull
  completion and install Camco/Schlumberger.
• Snorre UPA
• Halliburton remote hydraulic completion concept
  with 4 zones in well 34/7-A-01. Production start
  December 2000.