13 the acceptance of newer measurement technologies by global regulators (cameron)

Foro de Lineamientos de Medición México 2012

The Acceptance of Newer Measurement Technologies by

Global Regulators (A Brief Viewpoint)

Philip A Lawrence Director of Business Development

Cameron V&M , Houston TX USA.


ABSTRACT This paper will discuss -

• Some of the newer metering devices that are now being used to solve operational issues.

• Challenges that face world government oil and gas energy regulators in adopting these newer devices and applications.

• Standardization


Newer Metering Technologies (2- types will be to discussed due to time constraints)

• Ultrasonic Liquid Meters – Fiscal Usage

• Cone Type Differential Pressure Meters –

Gas Allocation and Separator Measurement


Newer Metering Technologies Ultrasonic Meters

• Advantages of Ultrasonic Metering Technology

• Acceptance of Technology, Standards Development & References


Newer Metering Technologies

Where: L = Path Length

C = Speed of Sound in the fluid

θ = Angle of sound path to the pipe axis

V = Average velocity along the pipe axis

The solution for fluid velocity is independent of the speed of sound

(C)

CosTT

TTLV

downup

downup

)(2

)(

Tup

Tdown

)( CosVC

LTup

)( CosVC

LTdown

θ

Ultrasonic Meters

L


7-22-11 6 PR-1004

Ultrasonic Flowmeters – No Longer New API Chapter 5 Section 2

Measurement of Liquid Hydrocarbons by Displacement Meters

API Chapter 5 Section 3 Measurement of Liquid Hydrocarbons by Turbine Meters

API Chapter 5 Section 6 Measurement of Liquid Hydrocarbons by Coriolis Meters.

API Chapter 5 Section 8 Measurement of Liquid Hydrocarbons by Ultrasonic Flowmeters Using Transit Time Technology

TC28/Sc2 - Measurement of Petroleum Products


Not All Liquid USM Meters are Equal Things to look for in a liquid USM-

• Accurate Geometry in the construction - Why ?

3D expansion of the body can change the path length in a poorly made device = poorer performance – forged housing better ! (grain structure)

•Transducer Design and Operation A short ring time whilst generating high dB signal – allows quicker pulse generation per block of time –in house manufacture gives better QA control.

•Ability to Test Properly on oil - ISO 17025 Laboratory Multiproduct Testing over Reynolds number range to characterize the meter

Transducer

Housings

RTD Temperature Probe

Caldon USM Device

Robust Manufacture


World class hydrocarbon

calibration facility

Temperature controlled

NMi Certified

ISO 17025 accredited

Traceable to international

standards

+/-0.04% Uncertainty

Not All Liquid USM Meters are Equal

Calibration Laboratory – Caldon USM’s


Cone Type Meters

High & Static

Pressure (A)

Low

Pressure (B)

Flow

Flow

Computer

Cone Meters are Used by Pemex for Allocation Metering


Higher Pressure.

Lower Pressure.

Conduit

Flow

L.P Tap

Computational Fluid Dynamics

HP LP RP

Cone Type Meter Flow Paths

Stream Lines Around DP Cone (CFD)


Low Pressure Port

Boundary Layer

D P

Fluid Linearization and Interaction in the Meter Throat

Keeps the Throat/Body of the Meter Clean by a Fluidic Sweeping Action (Computational Fluid Dynamics Image - CFD)

Fluid Flow

Common Velocity

Fluid Velocity Vector Interaction

Maximum - Annular

End View

Cone Type Meter Flow Paths


Generic Cone Meter Geometry – Improvements

Improvement by Some Manufacturers

Smooth Flow Entry With No Weld Bead (prevents jetting)


Not all Cone Meters Are Equal

Clean Internal finish to reduce surface

roughness / roundness and improve ReD

performance. ( courtesy Cameron V&M)

(Tolerance Per AGA 3 /ISO 5167 meter tube Designs –

(250-300 micro-inches) new idea for this meter type)

Multi-Gussets at the rear of the meter (better support and strength)

Type B Internal Weld

Flange Weld Removed and Cleaned

(Some Manufacturers)


Global Regulators Acceptance of Newer

Technology


Newer Technology History - Impact of equipment on the O&G business

1980 1990 2000 1940

Imp

act

on

th

e b

usin

ess (

AU

)

Start development

Coriolis Meters

UltraSonic Meters

Field introduction

Coriolis Meters

UltraSonic Meters

Field introduction

Multiphase meters Marginal impact on

field developments

Substantial impact

on field developments

Orifice meters

Turbine Meters

PD - Meters

Subsea/fiscal/

sub-surface metering

Start development

Multiphase meters


Global Regulators Acceptance of Newer Technology Production Measurement Needs - Who is really involved

Operations Maintenance free

Calibration free

Moderate accuracy

Trending

Third Parties Fiscal standards

Accuracy negotiable

Instrument Engineers What the customer wants

Standards,procedures, etc.

Government Bodies Fiscal standards

High accuracy

Reliable

Petroleum and Reservoir Engineers Moderate accuracy

Trending

Contract and Finance Fiscal standards

High accuracy

Reliable Sales parties Fiscal standards

High accuracy

Reliable

Traceable

Contracts

Custodian ? Auditable ?

Projects Options development

Project execution


Production Measurement - Organisation

Preferably in corporate part of the company

Knowledgeable of the entire metering chain

(from sensor to final report)

Focal point for companies metering philosophy/strategy

In-depth technical metering support

(new technology, standards, best practices, allocation

processes, fluid parameter management)

Liaison with both internal and external parties,

feel for what is required by “customers”

Company spokesman to 3rd parties and Government

Execute audits and reviews in the Asset Teams or BU’s

Production Measurement Team


Global Regulators Acceptance of Newer Technology

Are Not Only -

•Fiscal Standards ! API , ISO , OIML,

•High Accuracy ! Proving System & 3rd Party Auditing

•Reliability ! Meters are not to Defer Taxation

But may also include -

• Allocation Metering – which can be regulated

• Modern fields are increasingly using an allocation

location as a royalty point due to the Field Capacity to

Capex Ratio and the push to obtain Production from

Marginal Fields

• How about the Field End of Life

Major Requirements usually placed by a Government

Regulator on the Oil Company or Field Operator.


DTI (UK)Approach to Marginal Field Developments – Since 2000

When reviewing measurement proposals for a

“marginal field”, the DTI (UK DOE) is fully prepared to

relax some measurement requirements in the interest

of encouraging the development of remaining North

Sea oil and gas field potential.

Justification should include the following: • Relevant field economics

• Measurement options considered

• Costs of various project options

http://www.dti.gov.uk/index.html


Uncertainty (Cost or Risk)

Fiscal

(Allocation)


What are Critical Measurements

For oil wells 1) Net oil flow rate

2) Gross liquid flow rate

3) Water-Cut

4) GOR - Gas/Oil Ratio

5) FGOR - Formation GOR

For gas wells 1) Gas flow rate

2) CGR - Condensate/Gas Ratio

3) WGR - Water/Gas Ratio

In contrast with the

needs of the 80-90’s, which

presented the requirements in

terms of -

Oil, Water and Gas flow rates,

it now becomes clear that often

Water-Cut & GOR are also

prominent parameters.


Thin Oil Rim Development

Horizonta

l

We

ll

GOR –Control is Important

Oil

Pro

duction b

bl/d

2010 2016

120,000

20,000

Production profile

Total oil left

150 * 106 bbl

or

2,250 * 107 US$ 150$/bbl

• With sub-optimum production, e.g. gas coning/breakthrough

oil is lost and not deferred

• Assume 1% of oil is missed, this is equivalent to 225 * 106 US$

!! GOR Measurement is Critical

(May Not be Included In the Regulators Scope)


222

,,

,

2

,,

,

1

D

D

D

D

D

liquid

liquid

liftgtotalg

liftg

liftgtotalg

totalg

Q

Q

wc

wc

QQ

Q

QQ

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FGOR

FGOR

Field Longevity – Water-Cut !

oil

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liquidoil

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QQQ

,

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Reservoir

Qliquid

Qg,total

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M

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GOR – Control


High water-cut abandonment - end of life !

Breakeven if Revenues = Costs

or

oil produced = water treating costs

(1-wc) . QGROSS . 100 = wc . QGROSS . 2

W.C. approx. 98%

Too early shut-in

e.g. real W.C = 97%, measured W.C. = 98% (system error of +1%)

Loss of oil revenues (200 k$/year for a 500 m3/d well)

Too late shut-in

e.g. real W.C. = 99%, measured W.C. = 98% (syst. error of -1%)

Loss due to high water treating costs

Assume:

oil revenue 100 $/m3

water handling 2 $/m3



Standards - Accepted by Regulators

API Industry Standards Group – W.g’s by local oil company engineers

API - CPMA - Committee on Petroleum Measurement Allocation – Upstream

API – COGFM - Gas Flow Measurement – Mid & Downstream

API – COLM - Liquid Flow – Pipelines

API – COQM - Quality – sampling etc.

ISO - TC’s have W.g’s and Sub committee members with Country specified

industry experts and usually have Regulator Representatives usually managed

by the country standards body (USA = ANSI ) (UK = British Standards B.S.)

Example -

TC193 Natural Gas Measurement – Administration Holland

TC30 Meter Design Standards – Administration in UK



Conclusion

Global Regulators usually work with all parties to facilitate

a common goal which is -

• The Acceptance of New Technologies !

• Working with standardization groups can help to develop

new methods , since the regulator has had a first hand

input into the standard at the start.

• Well or field life strategy is important to make sure

revenues are not reduced by either shutting in too soon or

too late new technologies like multiphase metering and wet

gas systems help this

Engineering

13 the acceptance of newer measurement technologies by global regulators (cameron)