DTI Perpective Reservoir Surveillance

8/12/2019 DTI Perpective Reservoir Surveillance

1/24

Innovations in Reservoir Surveillance

DTI Perspective on Reservoir

Surveillance

Colin Cranfield

Reservoir Engineer

Licensing and Consents UnitAberdeen

15 September 2004


2/24


Quote from the late Laurie Dake*

Thorough data acquisition is expensive

(very expensive) and it is the duty ofpractising reservoir engineers to convince

those who hold the purse strings of the

necessity of the exercise.

* The Practice of Reservoir Engineering


3/24


Overview

DTI-LCU remit

PILOT initiatives

UKCS reserves

Brown field growth

Reservoir surveillance

General issues

Field observations

Conclusions


4/24


DTI-LCU aim

Maximise economic recovery of UK oil & gas

while minimising environmental impact


5/24


Reservoir surveillance is important throughout field

life

Need to establish economic viability of reservoir, .e.g EWTs

Gain reservoir understanding for effective management

Establish that reservoir is uneconomic prior to abandonment

Field

determination

issued

FDP

approved

Field

start-upCOP

AFRs submitted /

Addenda to FDPPre-development

discussions

Phased

development ?


6/24


PILOT targets

Government industry partnership

Striving to meet 2010 target


7/24


PILOT targets

Government industry partnership

Striving to meet 2010 target

Can only be achieved via

New field development

Brown field growth

Exploration success


8/24


UK production forecast (mmboe/d)

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

Possible new developments

Probable new developments upside

Brown field growth

Probable new developments

Approved fields Proven + Probable

Actual production Forecast UKCS oil and gas production 2003 - 2010

Source DTI 2003 annual reserves review

PILOT targets 2005 & 2010


9/24


DTI initiatives

PILOT

Fallow process

Promote licences

Access to data

Infrastructure code of practice

Brown field work group

Plus

Work with ITF on technology development

IOR conferences, web sites, eNewsletter


10/24


UKCS recovery factor distribution

Northern North SeaOil Recovery 43%

(upside 45%)

Southern North SeaGas Recovery 74%

(upside 78%)

-

Source DTI

Central North SeaOil Recovery 46%

(upside 49%)

Gas Recovery 65%(upside 71%)

Key

Oil Gas

Production to date

P+P Reserves

Possible reserves

Unrecovered


11/24


Improving brown field recovery

Reserves % increase 1991 - 2003

0

10

20

30

40

50

60

7080

90

V-fie

ldsBe

ryl

Thist

le

Vikin

g

Maur

een

Inde

Bren

t

Lem

an

More

cambe

Cam

elot

S.Br

ae

Fulm

ar

Forti

es

Mon

Arb

Clip

per

Heathe

r

Balm

oral

Auk

Sean

IV&

RR

Source UK Oil & Gas Commemorative Volumes


12/24


Brown field growth

Brown field WG addressing barriers

Typical success factors

Cost control Combining technologies

Technological advances

Drilling & completion

Geo-steering

Sub-sea tie-back Improved reservoir understanding

Integrated approach

3D/4D advances


13/24


By-passed & trapped oil

Causes

Reservoir compartmentalisation

Fault shadows

Heterogeneity

Attics

Opportunities

Better utilise injection

Infill / sidetrack locations

Well work / re-perforation / water or gas shut-off


14/24


15/24


1) Existing wells draining effectively?

Existing B2 perforations 10383 10423 ft md

Un-perforated 10423 10470 ft md

Existing B2 perforations 10478 10498 ft md

Massive sands

un-perforated intervals


16/24




17/24



Un-perforated interval 11,770 11,790 ft md

Channel sands

un-perforated interval


18/24



Gamma ray spikescould they be

horizontal barriers?


19/24


Typical surveillance approaches

Routine

RFT, LWD, logging

Production performance

Non-routine

3D/4D, geochem, geomech, SrRSA

Permanent surveillance

Difficulty in estimating value

More advanced cost/benefit analysis?


20/24


Andrew production & 4D surveys

-

10,000

20,000

30,000

40,000

50,000

60,000

70,000

80,000

90,000

100,000

110,000

120,000

130,000

140,000

150,000

Jun

-96

Sep

-96

Dec

-96

Mar-

97

Jun

-97

Sep

-97

Dec

-97

Mar-

98

Ju

l-98

Oc

t-98

Jan

-99

Apr-

99

Ju

l-99

Oc

t-99

Jan

-00

Apr-

00

Ju

l-00

Nov

-00

Fe

b-0

1

May

-01

Aug

-01

Nov

-01

Fe

b-0

2

May

-02

Aug

-02

Dec

-02

Mar-

03

Jun

-03

Sep

-03

Dec

-03

Fluid[bbls/d]

-

10,000

20,000

30,000

40,000

50,000

60,000

70,000

80,000

90,000

100,000

110,000

120,000

130,000

140,000

150,000

Gas[mscf/d]

Daily Water Volume bbl

Daily Oil Volume plbbl

Daily Gas Production

Baseline3D 2001 2002 2004D 4D Survey acquisition

MaximisingBrown fieldRecoveryOIL Rate

Water Rate


21/24


Surveillance challenges past and present

Compartmentalisation

Impacted injection strategies

Hydraulic fracturing Poorly controlled water injection

Marginal / sub-sea developments

Pre-drilled wells

Based on static data Non-optimum well placement

Defer injection wells?

Inaccurate zonal allocation

Inability to model reservoir


22/24


UKCS reserves categorised by development type

Source DTI web page

Platform Fields

Subsea tiebacks

Undeveloped

UKCS reserves

20 billion boe

Key

Developed P+P

Developed Fields Possible

SST P+P

SST Possible

Undeveloped Probable

Undeveloped Possible

Potential Additional

FPFs/FPSOs


23/24


Way forward - reservoir surveillance

Continue to refine and improve surveillance

Down-hole flow- & pressure-meters

By zone

Continue to integrate data observations

More sophisticated analysis

Tailor strategy to specific reservoir situation

Address key uncertainties

Develop case for thorough data acquisition


24/24


For DTI oil & gas information:

http://www.og.dti.gov.uk/

or contact:

[email protected]

01224 254066

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