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10/6/2005 Orders File Cover Page. doc
INDEX Conservation Order N0.505A
Orion Pool, Prudhoe Bay Field
1. February 23, 2006 Request for modifications to AIO 026 and CO 505 with
Exhibit attachments I-1, II-1, III-3, IV-1, through IV-8
and V-1, except IV-4 held Confidential
2. March 1, 2006 Advertising Order AO-02614029
3. March 29, 2006 E-mail re: hearing vacated
4. March 30, 2006 Exhibit IV-4 Confidentiality request
5. August 31, 2006 E-mail to operator re: reporting times
6. August 31, 2006 Prudhoe Bay Filed -Annual Surveillance Reporting
requirements to AOGCC
7. August 21, 2008 BPXA request to allow for the injection of
miscible injectant into multiple completion
injection wells (COSOSA-001)
Conservation Order N0.505A
e
e
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
333 West 7th Avenue, Suite 100
Anchorage Alaska 99501
Re: THE APPLICATION OF BP
EXPLORATION (ALASKA) INC. for
modification of Conservation Order 505 to
authorize underground injection of
enriched hydrocarbon gas for enhanced oil
recovery in Orion Oil Pool, Prudhoe Bay
Field, North Slope, Alaska
) Conservation Order No. 505A
) Prudhoe Bay Field
) Schrader Bluff Oil Pool
) Orion Development Area
)
) April 28, 2006
)
IT APPEARING THAT:
1. By application dated February 23, 2006 BP Exploration (Alaska) Inc. ("BPXA"),
Operator of the Prudhoe Bay Unit ("PBU"), requested an order from the Alaska Oil
and Gas Conservation Commission ("Commission") modifying Area Injection Order
26 ("AIO 26") and Conservation Order 505 to authorize the injection of enriched
hydrocarbon gas for enhanced oil recovery purposes in the Orion Oil Pool within the
PBU.
2. The Commission published notice of opportunity for a public hearing on BPXA's
application in the Anchorage Daily News on March 2, 2006.
3. The Commission received no requests for a public hearing.
4 The Commission received no protests or comments.
5. No hearing was held.
FINDINGS:
1. Description of Operation
BPXA requested authorization for an enhanced oil recovery ("EOR") project using
enriched gas from the Prudhoe Bay Central Gas Facility. The project involves the
cyclical injection of water alternating with injection of hydrocarbon gas enriched
with intermediate hydrocarbons, principally ethane and propane. Implementation of
the Orion EOR project will involve connection of Orion injection wells to existing or
new miscible gas injection distribution systems on L, V, and Z Pads. Enriched
hydrocarbon gas injection is expected to begin in 2nd quarter 2006.
Conservation Order 505A
April 28, 2006
e
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Page 2
2. CO 505, Rule 7:
CO 505 and AIO 26 approved and required the use of water injection. AIO 26A sets
out rules for injection of enriched hydrocarbon gas for the purposes of enhanced oil
recovery. Rule 7 of CO 505 should be updated to include enriched hydrocarbon gas
injection as an approved depletion plan option for the Orion Development Area of the
Schrader Bluff Oil Pool.
3. CO 505, Rule 9:
BPXA plans to monitor the composition of produced gas within offset producing
wells to determine the breakthrough volumes of enriched gas. This surveillance is
needed for evaluation of the effectiveness of the enriched gas flood. Rule 9 currently
includes a requirement that a surveillance report be submitted by April 1 of each year
and that a technical meeting with the Commission be conducted by June 1 of each
year. BPXA has requested that the due date of the surveillance report be revised to
September 15, with a technical meeting soon after. The surveillance report will cover
information for the period of July 1 of the prior calendar year through June 30 of the
current calendar year.
4. Consolidation of Orders:
CO 505 was approved on January 5, 2004. Since that time several new orders have
been issued which affect the Orion Oil Pool. These include the following: CO 492
added rules concerning the regulation of annulus pressures of development wells; CO
547 provided rules for use of multiphase meters for well testing in Prudhoe Bay Unit
Fields, including the Orion Oil Pool; and CO 556 added rules for waiver of
"Application for Sundry Approvals" for workover operations.
CONCLUSIONS:
1. Enriched gas injection will significantly improve recovery, and CO 505 should be
updated to allow for such injection.
2. Changing the due date for the Annual Reservoir Report from April 1 to September 15
will not affect the Commission's ability to evaluate reservoir performance or ensure
that future development plans promote greater ultimate recovery.
3. It is appropriate to consolidate Rules affecting the Orion Development Area of the
Schrader Bluff Oil Pool into one order.
NOW, THEREFORE, IT IS ORDERED THAT:
In addition to statewide requirements under 20 AAC 25 (to the extent not superseded by
these rules), the following rules apply to the Schrader Bluff Oil Pool within the following
affected area, referred to herein as the Orion Development Area, and supersede and
replace the rules adopted in Conservation Order 505:
Conservation Order 505A
April 28, 2006
e
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Page 3
Umiat Meridian
Township Lease Sections
Range, UM
TI2N-RlOE ADL 025637 13 and 24 N/2
T12N-RIIE ADL 047446 17, 18, 19, and 20
ADL 047447 16 S/2 and NW/4 and S/2 NE/4, 21,
and 22
ADL 028238 25 SW/4, 26, 35, and 36
ADL 028239 27, 28, 33 E/2 and N/2 NW/4, and 34
ADL 047449 29 N/2 and SE/4, and 30 N/2 NE/4
TIIN-RIIE ADL 028240 1,2, 11 E/2 and E/2 NW/4, and 12
ADL 028241 3 N/2 and N/2 S/2, and 4 NE/4 N/2
SE/4
ADL 028245 13 N/2 and SE/4, 14 E/2 NE/4, and
24 E/2 NE/4
TIIN-R12E ADL 047450 7, and 8 S/2 and NW/4
ADL 028263 16 SW/4 and S/2 NW/4, and 21
SW/4 and S/2 NW/4 and NW/4
NW/4 and W/2 SE/4
ADL 028262 17, 18, 19 N/2 and SE/4 and N/2
SW 14, and 20
ADL 047452 28 W/2 and W/2 E/2
ADL 047453 29 N/2 and N/2 SE/4
Rule 1: Well Spacing (CO 505)
Spacing units shall be a minimum of 10 acres. The Schrader Bluff Oil Pool shall not be
opened in any well closer than 500' to an external boundary where ownership changes.
Rule 2: Casing and Cementing Practices (CO 505)
a. In addition to the requirements of 20 AAC 25.030, conductor casing must be set
at least 75' below surface.
b. In addition to the requirements of 20 AAC 25.030, surface casing must be set at
least 500' TVD below the base of permafrost.
Rule 3: Automatic Shut-in Equipment (CO 505)
a. All wells must be equipped with a fail-safe automatic surface safety valve system
capable of preventing an uncontrolled flow.
b. All wells must be equipped with landing nipple at a depth below permafrost,
which is suitable for the future installation of a downhole flow control device.
The Commission may require such installation by administrative action.
Conservation Order 505A
April 28, 2006
e
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Page 4
c. Operation and performance tests must be conducted at intervals and times as
prescribed by the Commission to confirm that the safety valve systems are in
proper working condition.
Rule 4: Common Production Facilities and Surface Commingling (CO 505)
a. Production from the Schrader Bluff Oil Pool within the Orion Development Area
may be commingled with production from Prudhoe Bay Oil Pool, and other oil
pools located in the Prudhoe Bay Unit in surface facilities prior to custody
transfer.
b. The Prudhoe Bay Unit Western Operating Metering Plan, described by letter from
BPXA dated April 23, 2002 and detailed within the PBU Western Satellite
Production Metering Plan - Policies and Procedures Document" dated August 1,
2002 is approved for allocation of production from Schrader Bluff Oil Pool wells
within the Orion Development Area.
c. All Schrader Bluff Oil Pool wells must use the Gathering Center 2 well allocation
factor for oil, gas, and water.
d. All wells must be tested a minimum of once per month. All new wells must be
tested a minimum of two times per month during the first three months of
production. The Commission may require more frequent or longer tests if the
allocation quality deteriorates.
e. Technical process review meetings shall be held at least annually.
f. The operator shall submit a monthly report and file(s) containing daily allocation
data and daily test data for agency surveillance and evaluation.
Rule 5: Reservoir Pressure Monitoring (CO 505)
a. Prior to regular production or injection, an initial pressure survey must be taken in
each well.
b. A minimum of one bottom-hole pressure survey per producing governmental
section shall be run annually. The surveys in part (a) of this rule may be used to
fulfill the minimum requirements.
c. The reservoir pressure datum will be 4400' TVDss.
d. Pressure surveys may be stabilized static pressure measurements at bottom-hole
or extrapolated from surface (single phase fluid conditions), pressure fall-off,
pressure buildup, multi-rate tests, drill stem tests, and open-hole formation tests.
e. Data and results from pressure surveys shall be submitted with the annual
reservoir surveillance report. All data necessary for analysis of each survey need
not be submitted with the report but must be available to the Commission upon
request.
f. Results and data from special reservoir pressure monitoring tests shall also be
submitted in accordance with part (e) of this rule.
Conservation Order 505A
April 28, 2006
e
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Page 5
Rule 6: Gas-Oil Ratio Exemption (CO 505)
Wells producing from the Schrader Bluff Oil Pool within the Orion Development Area
are exempt from the gas-oil-ratio limits of 20 AAC 25.240 (a) so long as requirements of
20 AAC 25.240 (b) are met.
Rule 7: Enhanced Oil Recovery or Reservoir Pressure Maintenance Operations
(Amended this order - CO 505A)
Waterflood is required and enriched gas injection is approved for purposes of pressure
maintenance and enhanced oil recovery in the Orion Development Area of the Schrader
Bluff Oil Pool. Production and injection operations must ensure the average reservoir
pressure is maintained above the bubble point.
Rule 8: Multiple Completion of Water Injection Wells (CO 505)
a. Water injectors may be completed to allow for simultaneous injection in multiple
pools within the same well bore so long as mechanical isolation between pools is
demonstrated and approved by the Commission.
b. Prior to initiation of co-mingled injection, the Commission must approve methods
for allocation of injection to separate pools.
c. Results of logs or surveys used for determining the allocation of water injection
between pools, if applicable, must be supplied in the annual reservoir surveillance
report.
d. An approved injection order is required prior to commencement of injection in
each pool.
Rule 9: Annual Reservoir Review (Amended this Order - CO 505A)
An annual report must be filed by September 15 of each year. The report must include
future development plans, reservoir depletion plans, and surveillance information for the
period July 1 of the prior calendar year through June 30 of the current calendar year
(except the report due on September 15, 2006 must cover the period from January 2005
through June 30, 2006), and must include:
a. voidage balance by month of produced and injected fluids, and cumulative status;
b. reservoir pressure map at datum, summary and analysis of reservoir pressure
surveys within the pool;
c. results and, where appropriate, analysis of production and injection surveys, tracer
surveys, observation well surveys, and any other special monitoring;
d. review of pool production allocation factors and issues over the prior year;
e. progress of enhanced recovery project implementation and reservoir management
summary including results of reservoir simulation studies;
f. progress of plans and tests to expand the productive limits of the pool, including
any work within the Prince Creek formation; and
g. results of monitoring to determine enriched gas injectant breakthrough to offset
producers.
Conservation Order 505A
April 28, 2006
e
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Page 6
The Operator shall schedule and conduct a yearly technical review meeting with the
Commission to discuss the report contents and to review items that may require
Commission action during the coming year. The Commission may conduct audits of
technical data and analyses used in support of surveillance conclusions and reservoir
depletion plans.
Rule 10: Waiver of "Application for Sundry Approvals" Requirement for
Workover Operations (CO 556)
a. Except as provided in (d) and (e) of this rule, the requirement to submit an
Application for Sundry Approvals (Form 10-403) and supporting documentation
for workover activities described in 20 AAC 25.280 (a) (1), (2), (3) and (5) is
waived or modified for development wells as provided in the Commission
document entitled "Well Work Operations and Sundry Notice/Reporting
Requirements for Pools Subject to Sundry Waiver Rules," dated July 15, 2005
(referred to below as "Sundry Matrix"). This waiver and modification does not
affect the Operator's responsibility to submit a Report of Sundry Well Operations
(Form 10-404) within 30 days following the completion of a workover operation.
b. Except as provided in (d) and (e) of this rule, the requirement to submit an
Application for Sundry Approvals (Form 10-403) and supporting documentation
for workover activities described in 20 AAC 25.280 (a) (1) and (5) is modified for
service wells as provided in the Sundry Matrix. This modification does not affect
the Operator's responsibility to submit a Report of Sundry Well Operations (Form
10-404) within 30 days following the completion of a workover operation.
c. The Sundry Matrix summarizes the sundry approval and reporting requirements
that apply to various categories of operations in the specific well types under
Commission regulations as modified by these rules.
d. The waivers provided under (a) of this rule do not apply to wells that are required
to be reported to the Commission under the provisions of Rule 11.
e. The Commission reserves the discretion to require an operator to submit an
Application for Sundry Approvals for a particular well or for a particular
operation on any well.
f. Each week the Operator shall provide the Commission with a report of workover
operations performed the previous week that did not require submission of a Form
10-403. (These operations are listed in Column 2 of the Sundry Matrix.) The
report must include the date, well, permit to drill number, nominal operation
completed, and a brief description of that operation including depths of
perforations, reperforations, and stimulated zones.
g. Nothing in this rule precludes an Operator from filing an Application for Sundry
Approvals (Form 10-403) in advance of any well work or from including Sundry
authorized operations (listed in column 3 of the Sundry Matrix) in the weekly
report required by (£) of this rule.
h. Unless notice and public hearing are otherwise required, the Commission may
administratively waive the requirements of any provision of this rule or
Conservation Order 505A
April 28, 2006
e
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Page 7
administratively amend any provision including the Sundry Matrix, as long as the
change does not promote waste or jeopardize correlative rights, is based on sound
engineering and geoscience principles, and will not result in an increased risk of
fluid movement into freshwater.
Rule 11: Annular Pressures (CO 505, CO 492)
a. At the time of installation or replacement the Operator shall conduct and
document a pressure test of tubulars and completion equipment in each
development well that is sufficient to demonstrate that planned well operations
will not result in failure of well integrity, uncontrolled release of fluid or pressure,
or threat to human safety.
b. The Operator shall monitor each development well daily to check for sustained
pressure, except if prevented by extreme weather conditions, emergency
situations, or similar unavoidable circumstances. Monitoring results shall be
made available for Commission inspection.
c. The Operator shall notify the Commission within three working days after the
Operator identifies a well as having (a) sustained inner annulus pressure that
exceeds 2500 psig for wells processed through the Lisburne Processing Center
and 2000 psig for all other development wells, or (b) sustained outer annulus
pressure that exceeds 1000 psig.
d. The Commission may require the Operator to submit in an Application for Sundry
Approvals (Form 10-403) a proposal for corrective action or increased
surveillance for any development well having sustained pressure that exceeds a
limit set out in paragraph 3 of this rule. The Commission may approve the
Operator's proposal or may require other corrective action or surveillance. The
Commission may require that corrective action be verified by mechanical
integrity testing or other Commission approved diagnostic tests. The Operator
shall give the Commission sufficient notice of the testing schedule to allow the
Commission to witness the tests.
e. If the Operator identifies sustained pressure in the inner annulus of a development
well that exceeds 45% of the burst pressure rating of the well's production casing
for inner annulus pressure, or sustained pressure in the outer annulus that exceeds
45% of the burst pressure rating of the well's surface casing for outer annulus
pressure, the Operator shall notify the Commission within three working days and
take corrective action. Unless well conditions require the Operator to take
emergency corrective action before Commission approval can be obtained, the
Operator shall submit in an Application for Sundry Approvals (Form 10-403) a
proposal for corrective action. The Commission may approve the Operator's
proposal or may require other corrective action. The Commission may also
require that corrective action be verified by mechanical integrity testing or other
Commission approved diagnostic tests. The Operator shall give the Commission
sufficient notice of the testing schedule to allow Commission to witness the tests.
Conservation Order 505A
April 28, 2006
e
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Page 8
f. Except as otherwise approved by the Commission under (d) or (e) of this rule,
before a shut-in well is placed in service, any annulus pressure must be relieved to
a sufficient degree (1) that the inner annulus pressure at operating temperature
will be below 2000 psig, and (2) that the outer annulus pressure at operating
temperature will be below 1000 psig. However, a well that is subject to (c) but
not (e) of this rule may reach an annulus pressure at operating temperature that is
described in the Operator's notification to the Commission under (c) of this rule,
unless the Commission prescribes a different limit.
g. F or purposes of this rule,
"inner annulus" means the space in a well between tubing and production casing;
"outer annulus" means the space in a well between production casing and surface
casing; and
"sustained pressure" means pressure that (a) is measurable at the casing head of
an annulus, (b) is not caused solely by temperature fluctuations, and (c) is not
pressure that has been applied intentionally.
Rule 12: Use of Multiphase Flowmeters in Well Testing (CO 547)
For purposes of satisfying well test measurement requirements of 20 AAC 25.230, the
use of multiphase meters will be approved only in accordance with the provisions of the
Commission's document, "Guidelines for Qualification of Multiphase Meters for Well
Testing" dated November 30, 2004. The Commission may administratively waive a
requirement of these Guidelines or administratively amend the Guidelines as long as the
change does not promote waste or jeopardize correlative rights, and is based on sound
engineering and geoscience principles. This rule expires on January 1,2008.
Conservation Order 505A
April 28, 2006
e
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Page 9
Rule 13: Administrative Action
Unless notice and public hearing are otherwise required, the Commission may
administratively waive the requirements of any rule stated above or administratively
amend any rule as long as the change does not promote waste or jeopardize correlative
rights, is based on sound engineering and geoscience principles, and will not result in an
increased risk of fluid movement into freshwater.
DONE at Anchorage, Alaska and dated April 28, 200
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Daniel T. Seamount, Jr., Commissioner
Alaska Oil and Gas Conservation Commission
Cathy P. oerster, Commissioner
Alaska Oil and Gas Conservation Commission
AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person
affected by it may file with the Commission an application for rehearing. A request for rehearing must be
received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or
weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part
within 10 days. The Commission can refuse an application by not acting on it within the 10-day period.
An affected person has 30 days tram the date the Commission refuses the application or mails (or otherwise
distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to
Superior Court. Where a request for rehearing is denied by non-action of the Commission, the 30-day
period for appeal to Superior Court runs tram the date on which the request is deemed denied (i.e., loth day
after the application for rehearing was filed).
CO 505A and AIO 26A
e
e
Subject: CO 505A and AIO 26A
From: Jody Colombie <jody_colombie@admin.state.ak.us>
Date: Tue, 02 May 2006 10:32:42 -0800
To: undisclosed-recipients:;
BCC: Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen
<c.hansen@iogcc.state.okus>, Terrie Hubble <hubblet1@bp.com>, Sondra Stewman
<StewmaSD@BP.com>, stanekj <stan cal.com>, eco1aw <ecolaw@trustees.org>, trmjrl
<trmjr l@aol.com>, shaneg <shaneg s.com>, jdarlington <jdarlington@forestoil.com>,
nelson <knelson@petroleumnews.com>, c <cboddy@usibelli.com>, Mark Dalton
<mark.dalton@hdrinc.com>, Shannon Donnelly <sh . onnelly@conocophillips.com>, "Mark P.
Worcester" <markp. worcester@conocophillips.com>, <bob@inletkeeper.org>, wdv
<wdv@dnr.state.ak.us>, tjr dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson
<mjnelson ingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern"
<SkilleRL "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg"
<RossbeRS@BP. >, Lois <lois@inletke org>, Dan Bross <kuacnews@kuac.org>, Gordon
Pospisil <PospisG@BP.com>, "Francis S. S "<SommerFS@BP.com>, Mikel Schultz
<Mikel.Schultz@BP.com>, "Nick W. GI verNW@BP.com>, "Daryl J. Kleppin"
<KleppiDE@BP.com>, "Janet D. Platt" P.com>, "Rosanne M. Jacobsen"
<JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer
<barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov>, doug_schultze
<doug_sch energy. com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac
<yesnol@gc spfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred
Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, j ej ones <j ej ones@aurorapower.com>,
dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M.
Ruud" <james.m.ruu conocophillips.com>, Brit Lively <mapalaska@ak.net>,jah
<jah@dnr.state.ak.us , uonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>,
loren_IeIIl,an <loren_Ieman@gov.state.akus>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz
<jwkatz@sso.org>, Suzan J Hill <suzan _ hill@dec.state.ak.us>, tablerk <tablerk@unocal.com>, Brady
<brady@aog Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim
White <jimwhi tx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty
<marty@rkindustnal.com>, ghammons <ghammons@aol.com>, rmclean <rmclean@pobox.alaska.net>,
mkm7200 <mkm7200@aoLcom>, Brian' . <ifbmg@uaa.alaska.edu>, David L Boelens
<dboelens@aurorapower.com>, Todd Dur URKEE@KMG.com>, Gary Schultz
ultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon
nalaw.com>, Paul Winslow <pmwinslo forestoil.com>, Sharmaine Copeland
.com>, Kristin Dirks <kristin_dirks@dnr e.ak.us>, Kaynell Zeman
. athonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler
<Bill_Fo adarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim
<mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>,jack newell <jacknewell@acsalaska.net>,
James Scherr <james.scherr@mms.gov>, n1617@conocophillips.com, Tim Lawlor
<Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs
<Jerry.C.Dethlef: ocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>,
Jon Goltz·<Jon. z@conocophillips.co ger Belman <roger.belman@conocophillips.com>,
Mindy Lewis <mlewis@brenalaw.com> riarty <moriarty@aoga.org>, Patty Alfaro
<palfaro@yahoo.com>, Jeff <smet al.com>, Todd Kratz <ToddKratz@chevron.com>, Gary
Rogers <gary_rogers@revenue.state.ak hur Copoulos <Arthur_Copoulos@dnr.state.ak.us>, Ken
<ken@secorp-inc.com>, Steve Lambe bert@unocal.com>, Joe Nicks <news@radiokenai.com>,
Jerry McCutcheon <susitnahydronow@yahoo.com>, Paul Todd <paulto@acsalaska.net>, Bill Walker
10f2
5/2/2006 10:36 AM
CO 505A and AIO 26A
e e
<bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker
<paul_decker@dnr.state.ak.us>, Rob Dragnich <ro agnich@exxonmobi1.com>, Aleutians East
Boro admin@aleutianseast.org arquerite kr <marguerite_kremer@dnr.state.ak.us>, Robert
Brelsobert.Bre1sford@arg iagroup.com> 'cia Konsor <alicia_konsor@dnr.state.ak.us>,
Mike <mike@kbbi.org>, d Robinson <gb ·nson@marathonoi1.com>, Cammy Taylor
<Cami law.state.ak.us 'nton GAubert n_aubert@admin.state.ak.us>, Thomas E
de _maunder@admin. te.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>,
Kei Wiles <kwiles@marathonoi1.com>, Cynthia B Mciver <bren_mciver@admin.state.ak.us>
ontent- Type: application/pdf
ontent-Encoding: base64
I
r Content-Type: application/pdf
¡AI026A.pdf Content-Encoding: base64
I
20f2
5/2/200610:36 AM
Mary Jones
XTO Energy, Inc.
Cartography
810 Houston Street, Ste 2000
Ft. Worth, TX 76102-6298
George Vaught, Jr.
PO Box 13557
Denver, CO 80201-3557
John Levorsen
200 North 3rd Street, #1202
Boise, 10 83702
Michael Parks
Marple's Business Newsletter
117 West Mercer St. Ste 200
Seattle, WA 98119-3960
Ciri
Land Department
PO Box 93330
Ànchorage, AK 99503
Jill Schneider
US Geological Survey
4200 University Dr.
Anchorage, AK 99508
Darwin Waldsmith
PO Box 39309
Ninilchick. AK 99639
Penny Vadla
399 West Riverview Avenue
Soldotna, AK 99669-7714
Bernie Karl
K&K Recycling Inc.
PO Box 58055
Fairbanks, AK 99711
e
David McCaleb
IHS Energy Group
GEPS
5333 Westheimer, Ste 100
Houston, TX 77056
Jerry Hodgden
Hodgden Oil Company
408 18th Street
Golden, CO 80401-2433
Kay Munger
Munger Oil Information Service, Inc
PO Box 45738
Los Angeles, CA 90045-0738
Mark Wedman
Halliburton
6900 Arctic Blvd.
Anchorage, AK 99502
Baker Oil Tools
4730 Business Park Blvd., #44
Anchorage. AK 99503
Gordon Severson
3201 Westmar Cr.
Anchorage, AK 99508-4336
James Gibbs
PO Box 1597
Soldotna. AK 99669
Richard Wagner
PO Box 60868
Fairbanks, AK 99706
North Slope Borough
PO Box 69
Barrow, AK 99723
e
Mona Dickens
Tesoro Refining and Marketing Co.
Supply & Distribution
300 Concord Plaza Drive
San Antonio, TX 78216
Richard Neahring
NRG Associates
President
PO Box 1655
Colorado Springs, CO 80901
Samuel Van Vactor
Economic Insight Inc.
3004 SW First Ave.
Portland, OR 97201
Schlumberger
Drilling and Measurements
2525 Gambell Street #400
Anchorage, AK 99503
Ivan Gillian
9649 Musket Bell Cr.#5
Anchorage, AK 99507
Jack Hakkila
PO Box 190083
Anchorage, AK 99519
Kenai National Wildlife Refuge
Refuge Manager
PO Box 2139
Soldotna. AK 99669-2139
Cliff Burglin
PO Box 70131
Fairbanks, AK 99707
Williams Thomas
Arctic Slope Regional Corporation
Land Department
PO Box 129
Barrow, AK 99723
Mary Jones
XTO Energy, Inc.
Cartography
810 Houston Street, Ste 2000
Ft. Worth, TX 76102-6298
George Vaught, Jr.
PO Box 13557
Denver, CO 80201-3557
John Levorsen
200 North 3rd Street, #1202
Boise, 10 83702
Michael Parks
Marple's Business Newsletter
117 West Mercer St, Ste 200
Seattle, W A 98119-3960
Ciri
Land Department
PO Box 93330
Anchorage, AK 99503
Jill Schneider
US Geological Survey
4200 University Dr.
Anchorage, AK 99508
Darwin Waldsmith
PO Box 39309
Ninilchick, AK 99639
Penny Vadla
399 West Riverview Avenue
Soldotna, AK 99669-7714
Bernie Karl
K&K Recycling Inc.
PO Box 58055
Fairbanks, AK 99711
e
David McCaleb
IHS Energy Group
GEPS
5333 Westheimer, Ste 100
Houston, TX 77056
Jerry Hodgden
Hodgden Oil Company
408 18th Street
Golden, CO 80401-2433
Kay Munger
Munger Oil Information Service, Inc
PO Box 45738
Los Angeles, CA 90045-0738
Mark Wedman
Halliburton
6900 Arctic Blvd.
Anchorage, AK 99502
Baker Oil Tools
4730 Business Park Blvd., #44
Anchorage, AK 99503
Gordon Severson
3201 Westmar Cr.
Anchorage, AK 99508-4336
James Gibbs
PO Box 1597
Soldotna, AK 99669
Richard Wagner
PO Box 60868
Fairbanks, AK 99706
North Slope Borough
PO Box 69
Barrow, AK 99723
e
Mona Dickens
Tesoro Refining and Marketing Co.
Supply & Distribution
300 Concord Plaza Drive
San Antonio, TX 78216
Richard Neahring
NRG Associates
President
PO Box 1655
Colorado Springs, CO 80901
Samuel Van Vactor
Economic Insight Inc.
3004 SW First Ave.
Portland, OR 97201
Schlumberger
Drilling and Measurements
2525 Gambell Street #400
Anchorage, AK 99503
Ivan Gillian
9649 Musket Bell Cr.#5
Anchorage, AK 99507
Jack Hakkila
PO Box 190083
Anchorage, AK 99519
Kenai National Wildlife Refuge
Refuge Manager
PO Box 2139
Soldotna, AK 99669-2139
Cliff Burglin
PO Box 70131
Fairbanks, AK 99707
Williams Thomas
Arctic Slope Regional Corporation
Land Department
PO Box 129
Barrow, AK 99723
~~ 0 d a a
SARAH PALIN, GOVERNOR
lZi~[>•-7~ OIIl ~ GAS 333 W. 7th AVENUE, SUITE 100
C01~5ERQA7'IO1~T COMhIIS5I01'1T ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
ADMINISTRATIVE APPROVAL CO SOSA.001 (ORION OIL POOL)
ADMINISTRATIVE APPROVAL AIO 26A.002 (ORION OIL POOL)
ADMINISTRATIVE APPROVAL CO 471.007 (BOREALIS OIL POOL)
Mr. Frank Paskvan
GPB Western Region Resource Manager
BP Exploration (Alaska) Inc.
P.O. Box 196612
Anchorage, AK 99519-66612
RE: Application for Modification of Conservation Order SOSA and Area Injection Order 26A,
Orion Oil Pool and Commission Motion to Amend Conservation Order 471, Borealis Oil
Pool to Authorize Commingled Miscible Injectant (MI) Injection and Approve a Method
for Allocating MI Injection Between the two Pools
Dear Mr. Paskvan:
In accordance with Rule 13 of Conservation Order (CO) SOSA, Rule 10 of CO 471, and Rule 11
of Area Injection Order (AIO) 26A, the Alaska Oil and Gas Conservation Commission
(Commission) administrative approves the commingled injection of miscible injectant (MI) in the
Prudhoe Bay Unit (PBU) L-103 and PBU V-105 wells in the Orion and Borealis Oil Pools.
By letter dated August 21, 2008, and received by the Commission on August 22, 2008, BP
Exploration (Alaska) Inc. (BPXA) requested that the Commission amend CO SOSA and AIO 26A
to allow commingled injection of MI in some wells that are approved for the commingled
injection of water. Because the application involves commingled injection within two oil pools, it
should also have addressed CO 471. Therefore, the Commission, on its own motion, is
considering BPXA's application as an application to amend CO 471, as well.
Rule 3 of AIO 26A and Rule 2 of AIO 24B authorize the injection of MI into the Orion and
Borealis Oil Pools, respectively. Rule 8 of CO SOSA, Rule 6 of AIO 26A, and Rule 8 of CO 471
authorize the commingled injection of water in these pools.
BPXA requests the elimination of the reference to water in Rule 8 of CO SOSA, Rule 6 of AIO
26A, and Rule 8 of CO 471 so that other approved fluids can be injected in the commingled
injectors. BPXA specifically requests authorization to inject MI into two commingled injectors:
the PBU L-103 and P$U V-105 wells. Both wells are classified as water alternating gas injection
wells and, as such, have been approved for MI injection. The wells have also been approved for
use as commingled water injection wells. Both wells have been used for commingled water
injection and are being used for MI injection into the Borealis Oil Pool; the Orion Oil Pool was
CO SOSA.001; AIO 26A.002,;'CO 471.007
November 10, 2008
Page 2 of 2
shut-off in these wells. Therefore, the wells appear to have the necessary mechanical integrity
to be used as commingled MI injection wells.
BPXA also requests approval of a method of allocating MI injection volumes between the two
pools by means of a downhole regulator valve that shows a very distinct correlation between
injection pressure and. MI flow rate. BPXA also proposes to conduct injection profiles in these
wells on a routine basis to ensure that the correlation between the injection pressure and MI flow
rate remains valid. The proposed allocation methodology described by BPXA in the August 21,
2008, application will provide adequate results.
Accordingly, with the conditions below, Rule 8 of CO 471, Rule 8 of CO SOSA, and Rule 6 of
AIO 26A are amended to remove the word "water": these amendments do not promote waste or
jeopardize correlative rights, are based on sound engineering and geoscience principles, and will
not result in an increased risk of fluid movement into freshwater.
Conditions:
1) Commingled MI injection is authorized for the PBU L-103 and PBU V-105 wells only.
The Commission will consider approving commingled MI injection for other wells by
administrative action upon application by the operator.
2) MI injection in the wells must be allocated to the subject pools in accordance with t~-
i~~t.
method BPXA proposed in its August 21, 2008 application. ~~,=-°"~`~~~ .
All other terms and conditions of the affected orders remain unchanged. ` t '` '
f~ ~
~
a ' ~ f.
~' `~`
~
_
ENTERED at Anchorage, Alaska, and dated November 10, ~
~' ,
.o w 1 ~a
'~~,,a ,o .
s.., .. M,..•^°
Daniel T. Seamount, Jr. Cathy . Foerster n ~. Norman
Chair Com issioner Comm'~ner
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission
grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined
by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the
order or decision is believed to be erroneous.
The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it
within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of
reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the
Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is
by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed.
If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on
reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed
within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on
reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission
by the application for reconsideration."
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period;
the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day
that does not fall on a weekend or state holiday
Mary Jones David McCaleb Cindi Walker
XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co.
Cartography GEPS Supply & Distribution
810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive
Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216
George Vaught, Jr. Jerry Hodgden Richard Neahring
PO Box 13557 Hodgden Oil Company NRG Associates
Denver, CO 80201-3557 408 18th Street President
Golden, CO 80401-2433 PO Box 1655
Colorado Springs, CO 80901
Mark Wedman Schlumberger Ciri
Halliburton Drilling and Measurements Land Department
6900 Arctic Blvd. 2525 Gambell Street #400 PO Box 93330
Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503
Baker Oil Tools Ivan Gillian Jill Schneider
4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey
Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr.
Anchorage, AK 99508
Gordon Severson Jack Hakkila Darwin Waldsmith
3201 Westmar Cr. PO Box 190083 PO Box 39309
Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639
James Gibbs Kenai National Wildlife Refuge Penny Vadla
PO Box 1597 Refuge Manager 399 West Riverview Avenue
Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714
Soldotna, AK 99669-2139
Richard Wagner Cliff Burglin Bernie Karl
PO Box 60868 PO Box 70131 K&K Recycling Inc.
Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055
Fairbanks, AK 99711
North Slope Borough
PO Box 69
Barrow. AK 99723
~~~/d
i~~i2~P
• ~ Page 1 of 1
Colombie, Jody J (DOA)
From: Colombie, Jody J (DOA)
Sent: Wednesday, November 12, 2008 10:33 AM
Subject: co505A-001 (Orion) aio26A-002 (Orion) co471-007 (Borealis) erio3-001 (West McArthur River)
Attachments: erio3-001.pdf; co505A-001 A1026A-002 CO 341-007.pdf
BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Joe Longo'; 'Lamont
Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve
Virant'; Tom Gennings; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C (DNR); 'Aleutians East
Borough'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie';
'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Cary
Carrigan'; 'Charles O'Donnell'; 'Chris Gay'; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David
Hall'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; 'Deborah J. Jones'; 'doug_schultze'; 'Eric Lidj i ';
'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary
Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gregory micailef; 'gspfoff;
'Hank Alford'; 'Harry Engel'; 'jah'; 'James Scherr'; 'Janet D. Platt'; 'jejones'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim
White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz';
johnny.aiken@north-slope.org; 'Jon Goltz'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles';
knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Dirks'; 'Laura Silliphant'; 'Lois'; 'Lynnda Kahn';
'mail=akpratts@acsalaska.net'; 'mail=fours@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark
Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; 'Matt Rader'; Melanie Brown; 'Mike Bill'; 'Mike Mason'; 'Mikel
Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nick W. Glover'; NSK Problem Well Supv; NSU,
ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Decker'; 'Paul Winslow'; Pierce, Sandra M (DNR); 'Randall
Kanady'; 'Randy L. Skillern'; 'rcrotty'; Rice, Cody J (DNR); 'rmclean'; 'Rob McWhorter ';
rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Fowler'; 'Robert Province'; 'Roger Belman'; 'Rudy
Brueggeman'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan
Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Temple
Davidson'; 'Terrie Hubble'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; 'Walter Quay';
'Wayne Rancier'; Birnbaum, Alan J (LAW); Crisp, John H (DOA); Davies, Stephen F (DOA); Fleckenstein, Robert J
(DOA); Foerster, Catherine P (DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M (DOA); Jones, Jeffery B (DOA);
Laasch, Linda K (DOA); Mahnken, Christine R (DOA); Maunder, Thomas E (DOA); McIver, C (DOA); McMains,
Stephen E (DOA); Noble, Robert C (DOA); Norman, John K (DOA); Okland, Howard D (DOA); Paladijczuk, Tracie L
(DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S (DOA); Saltmarsh, Arthur C (DOA); Scheve,
Charles M (DOA); Seamount, Dan T (DOA); Smith, Chasity R (DOA); Williamson, Mary J (DOA)
Attachments:erio3-OO1.pdf;co505A-001 AI026A-002 CO 341-007.pdf;
Jody J. Colombie
Special Assistant to the Commission
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
(907) 793-1221 Direct Line
(907) 276-7542 Fax
11/12/2008
~7
by
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P. 0. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
1l ..`
August 21, 2008
Daniel T. Seamount, Jr.
Chairman
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
BUG ~ ~ zC~
Alaska Oii & Gas Cn~s. ~.`~mmssior
Anchor!
RE: Application for Modification of Conservation Order 505A and Area
Injection Order 26A, Orion Oil Pool
Application for Commission Approval on Method of MI Commingled
Injection Allocation
Dear Chairman Seamount:
BP Exploration (Alaska), Inc. (BPXA), operator of the Prudhoe Bay Unit (PBU),
on behalf of itself and the other the PBU Working Interest Owners, requests
modification of Conservation Order No. 505A (CO 505A) and Area Injection
Order No. 26A (A1O 26A) to allow for the injection of miscible injectant (MI) into
multiple completion injection wells (commingled Borealis/Orion injectors) to
enhance recovery from the Orion Oil Pool.
A1O 26A and CO 505A allow for injection of enriched hydrocarbon gas into the
Orion Oil Pool, but current language limits Orion Oil Pool injection into
"commingled" injection wells to water only. These commingled wells have
provided important Orion reservoir support while injecting water, but recently
have been shut-in to the Orion interval while the Borealis interval is on the MI
portion of its WAG cycle. Modification of these orders to allow for Orion MI
injection into "multiple completion" injectors will greatly improve their utility in
supporting the Orion reservoir. BPXA's January 23, 2006 request to allow MI
injection into the Orion Oil Pool inadvertently overlooked the commingled well
language limiting injection to water only. Use of these wells in a WAG injection
capacity is part of our depletion plan to maximize Orion Oil Pool recovery.
BPXA proposes modifications to A1O 26A Rule 6 and CO 505A Rule 8 by
removing the limiter "water" from the references to "water injectors". The title of
these rules and subsection (a) would be amended to read as follows:
• •
Multiple Completion of Infection Wells
a. Injectors may be completed to allow for injection in multiple pools
within the same wellbore so long as mechanical isolation between
pools is demonstrated and approved by the Commission.
In addition, BPXA seeks Commission approval of a method for allocating MI
injection fluids as required by A10 26A Rule 6(b) and CO 505A Rule 8(b). A
detailed description of equipment testing to accurately regulate MI injection
between Pools, and an allocation method proposal are enclosed.
Although the Commission has approved the one-quarter mile mechanical
condition of the commingled injectors, attached is a new area-of-review that
revisits the prior analysis and includes recent penetrations. At this time,
commingled injection is requested in two injectors, L-103 and V-105, so the
review focuses on these wells.
Should you have any questions regarding this request, please contact me at 564-
5749 or Taylor West at 564-4647.
Thank you for your timely consideration of this request.
Sincerely,
~~~~~
r rr~n
GPB Western Region Resource Manager
Enclosures
CC: Sonny Rix (ExxonMobil) Dan Kruse (CPAI)
Glenn Frederick (Chevron) Paul Winslow (Forest Oil)
Claire Sullivan (BPXA) Sherri Gould (BPXA)
David Lenig (BPXA) Taylor West (BPXA)
• •
Discussion:
Commingled Infector Background:
The Commission determined in A10 26 Finding 9 that five Borealis wells were
mechanically competent to be used for commingled injection into the Borealis
Oil Pool and the mechanically-straddled Orion Oil Pool: L-103, L-111, L-115,
L-117, and V-105. In 2003, BPXA demonstrated a method to mechanically
split water injection between zones using a Schlumberger downhole
waterflood regulating valve (WFR) installed adjacent to the straddled Orion
interval. The WFR regulates water injection volume to a high degree of
accuracy across a broad range of injection pressure. The Commission
subsequently approved the injection allocation method in accordance with
A10 26, Rule 7(b), and CO 505 Rule 8(b), after which commingled water
injection began in three commingled injectors: L-103, L-117, and V-105. In
the last year, these injectors, which are permitted for WAG injection, have
begun miscible injectant (MI) injection into the Borealis Pool, which required
the shut-off of the Orion interval. Approval of MI injection into the Orion
interval in these wells is needed in order to maintain proper reservoir voidage
and injection support.
MI regulating valve qualification:
A test was run in the summer of 2007 on a different style of replaceable
downhole regulator valve designed for gas injection applications. The valve,
supplied by Schlumberger under the name "NOVA", is a highly engineered
venturi that produces a linear injection rate profile across a wide range of
injection pressures. The valve has no moving parts, and would be installed in
aside-pocket mandrel adjacent to the Orion straddled interval. The valve's
behavior is well understood by the manufacturer under dry gas applications,
but not in a MI application due to the unique properties of enriched
hydrocarbon gas. To determine this, a NOVA valve was installed in Orion
injector L-2131, which at the time was on MI injection, and then a number of
step-rate injection tests were performed to characterize the regulating
behavior on MI injection.
Data from the injection test is shown in Figures 1 and 2. The step-rate tests
confirmed that the valve controlled the injection rate in a linear fashion across
the range of injection pressures expected in the commingled injectors. A
simple pressure vs. rate correlation was derived, and if applied to the average
daily wellhead injection pressure on a commingled injector, would yield an
accurate allocation split between the Orion and Borealis intervals. BPXA
proposes to install a NOVA valve in the straddled Orion interval of a
commingled MI injector, thereby accurately regulating the flow of MI gas to
the lower-pressured Orion interval. At month-end, the BP pad engineer will
allocate injection between the pools using the simple rate/pressure algorithm.
•
Figure 3 shows a hypothetical example of this calculation using historical MI
injection data from commingled injector L-103. Currently, only a single NOVA
valve size has been characterized, but it is expected to cover the desired
injection rates, and therefore no qualifications of other valve sizes are
planned. Periodic injection profile logs are also proposed in order to confirm
the ongoing performance of the NOVA valve.
1) In wells approved for commingled MI injection, BP will use a NOVA
valve to regulate MI flow into the Orion Pool.
2) Daily allocation of injectant volumes between Pools will be calculated
as a function of average daily wellhead injection pressure.
3) BP will verify calculated injection splits by obtaining an injection profile
within three months of the start of MI commingled injection, and then
approximately every 6 months thereafter as long as commingled MI
injection continues.
L-213 MI NOVA Valve Test - 8/64 orifice
3500
3000
2500
N
a
d
7 2000
tl!
v
~ 1500
0
1000
500
0 ~--
6/29/07
12:00
• inj pressure
^ MI flow
6/30/07 6/30/07 7/1/07 7/1/07 7/2/07 7/2/07
0:00 12:00 0:00 12:00 0:00 12:00
Tim e
2.5
2
0
a
LL
N
1.5 ~
d
3
0
1 ~
-' 0.5
7/3/07
0:00
Figure 1 - L-213 NOVA Valve Step-Rate Test Data
L-213 MI NOVA Valve Test - 8/64 Orifice
3 --.. - ------- - - l
I
2.5
a ~ ~~`~
v =-M . _ _ .
w 2 ~, ..- -
~ ~ ~ ~.
d
is 1.5 ~ ~ - _ _ _ _ _ _ _ _ -
c
° MI injection rate = 0.0005 x injection pressure + 0.7589
~~
m 1,
'c
~ i III
0.5 i-- -- -I
01 I
1000 1500 2000 2500 3000 3500
Injection pressure psi
Figure 2 -NOVA Rate Algorithm
Orion
L-103 L-103 Gas
Inj Vol Metered Wellhead Pres (via Nova)
MSCFPD PSI MSCFPD
2,168 2,361 1954
2,110 2,317 1932
4,652 2,376 1962
2,830 2,342 1945
3,182 2,336 1942
3,290 2,322 1935
2,978 2,315 1931
3,888 2,329 1938
8,128 2,669 2108
13,036 2,705 2126
11,838 2,722 2135
10,862 2,725 2136
10,834 2,727 2137
11,114 2,757 2152
9,890 2,724 2136
9,142 2,734 2141
9,544 2,741 2144
9,832 2,761 2154
Orion injection volume = 0.5 x
injection pressure + 759
Borealis Orion
Gas Fraction
MSCFPD
214 90%
178 92%
2,690 42%
885 69%
1,240 61
1,355 59%
1,047 65%
1,950 50%
6,020 26%
10,910 16%
9,703 18%
8,726 20%
8,697 20%
8,962 19%
7,754 22%
7,001 23%
7,400 22%
7,678 22%
Borealis injection volume =total well
metered volume metered -Orion gas
Figure 3: Hypothetical Calculation Using Historic Pressure and Rate Data
• •
Infector mechanical isolation area of review
C~
n
BP proposes MI injection into the Orion interval of V-1051 and L-1031. Both wells were found to be in compliance with 20 AAC
25.030 per Area Injection Order 26, Finding 9.
All wells show good mechanical isolation at the Orion interval.
Zonal isolation status of wellbores within one-quarter mile of V-105i is summarized below (see Figure 4):
Well Date
Drilled Distance
from
in'ector TOC TOC
Determination
Method Top Pool
(Na sand) Top Injection
Sand (OA) Coverage/ Comments
V-105 8-02 0 4600' and Cement l0 5204' and 5993' and 600' and above ool
V-106a 10-04 526 4496' and Calculated,
w/30% excess 5275' and 5495' and 779' and above pool
V-07 12-07 730 3120' and Cement l0 5075' and 5266' and >1900' and above the ool
V-222i 6-07 857 3720' and Cement l0 4543' and 4722' and 823' and above ool
V-202 5-03 1244 NA NA NA NA Offset Orion Producer
V-204 7-04 1034 NA NA NA NA Offset Orion Producer
Note: V-105 was cemented in two stages, with the base of good Schrader cement at 5803' md, 156' below the lowermost
injection sand (OBd).
Zonal isolation status of wellbores within one-quarter mile of L-103i is summarized below (see Figure 5):
Well Date Distance TOC TOC Top Pool Top Injection Coverage/ Comments
Drilled from Determination (Na sand) Sand (OA)
in'ector Method
L-103i 7-02 0 4460 Cement l0 5636' and 5892' and 1176' and above ool
L-120 2-02 239' 5099 Calc w/30% 5675' and 5961' and 576' and above pool
excess
L-201 3-04 918' NA NA NA NA Offset Orion Producer
Orion V Pad Area
Well V-105 114 Mile Radius Map
Structure on Top OA sand
V-222 Well within 114 mile of V-105 at Schrader Pool level.
Figure 4 - V-105i'/a mile radius map
• •
• Top Na Sand (Top Schrader Bluff Pool) Well V-105
• Top OA Sand 1/4 Mile
• Base OBf Sand (Base Schrader Bluff Pooh Radius ClfCle
Qrion L Pad Area
• Top Na Sand (Top Schrader Bluff Pool)
• Top OA Sand
~ Base OBf Sand (Base Schrader Bluff Pool)
Well L-103
1/4 Mile
Radius Circle
L-120 Well within 114 mile of L-103 at Schrader Pool level.
Figure 5 - L-103 '/a mile radius map
~ •
Well L-103 1 /4 Mile Radius Map
Structure on Top OA sand
·~6
Prudhoe Bay Field - Annual Surveillance Reporting Requirements to AOGCC
Group 1 IPA Group 2 GPMA Group 3 Satellites
- -~---~..,.__..,...._--------_... --------- t-------- - ---
Annual Surveillance Report 15-Mar 15-Jun 15-Sep
1------- --------.------------~ I-------------_._-~~ - - -----------~
_.._--._._-~-_._._--_."--~-_.._,---_.._-_._--- -----------~----- 1----------------------
Annual Overview Presentation 22-Mar 22-Jun 22-Sep
------------------~ .---- -- ----.,---.'--.- ----------
.--- - ---
Production Period to be Covered Jan 1-Dec 31 Apr 1-Mar 31 Jul 1-Jun 30
Amends Order/Rule
Group 1 - IPA OilJ:»_()~I~_________
~...~--,--"._--,._--~-_.-
Prudhoe Oil Pool C0341 D Rule 11
----, , _..___,...________.,._._._______._______~_ __ ~__~,_,_~.._._.,_. .________ o'·__n.'_...'·__
Put River Oil Pool C0559
ºr()IJ.e.2:-ºPIVI~_OiL~~()ls__________ _
Order Date
11/30/2001
11/22/2005
.
Comment
Note C0341 E (modified Pool Definition to
include a portion of Put River Sandstone)
Corrected 2/14/2006
---._~-'----~---'---
-,._,--------~--_._--_.- ----------_.-.
__~o rule on Su~eillance repo!!s
Lisburne C0207, 207 A
_.._.__._---------,----~ - -_.__.._._--------_.~-_._------_.. ---
Niakuk C0329A Rule 9
.--.-------..... ...__.'. --.. . -". ---~----"'-''"'-,---~.-._~- --.....--.---
. _~_____________~.Jorth_~ædho~ Bay C0345 Rule 8
__________?t. ~clntyre ____-º0317B Rule 15
Raven Oil Pool C0570 Rule 10
- -.----.- ..._~..----_.~--------~--_._~._.~----_.__..._-~_._.~-.~.~
West Beach Oil Pool C0311 BRule 13
._---~-----_._-
6/4/1996
12/16/1994
4/19/2000
8/9/2006
~._._-_.
8/1/2000
4~=-~-=-=- - . ----
.
º~~IJP _ ~__-_J:»!udh~!..ª-~telli!~ O~~~ool!S_ _____________~_____ _______~____~_________________________
.... _,6.lJ!ora__-ºº~57B .B.uJ~ª______~_?125/200.±________.J..corrected 8/9/2004)
Boreallis C0471 Rule 4 5/29/2002
._.._.,____.___'.._.._.___.n'.._.__."._'''______ ~~___._____..____.____.".__.~.___._ ___~_.~~_
._._~lci.~i9_~!.ªIJ.!'~_ C0452 Rule 11 ____m____ 11/15/2000
Orion C0505A Rule 9 4/28/2006
__.._____.__~_.. ___.___~_ _ __________ ____..._..__..,__.___________.__ ____._~________._._.m___~_
Polaris C0484A Rule 9 11/3/2005
_....._--_...__._--~---_._-----~----,,---.__._~---_......._._-~--.-
__ +__m_______ ____ ____
~___....__________L_____.. _ ____._._..__ .. ..__.__________________~,_.___
I
l.... ,. ...... l.... ., -- ~~_. ............. _....~_£.._- ..-t''''.... --"'-""jJ
.
.
Subject: [Fwd: [Fwd: Re: surveillance report dates]]
From: Jane Williamson <jane _ williamson@admin.state.ak.us>
Date: Fri, 20 Apr 2007 13:03:59 -0800
To: Jody J Colombie <jody_colombie@admin.state.ak.us>, Dave Roby <dave_roby@admin.state.ak.us>,
Cathy P Foerster <cathy _ foerster@admin.state.ak.us>, Alan J Birnbaum
<alan _ birnbaum@law.state.ak.us>
cc: Stephen E Mcmains <steve_mcmains@admin.state.ak.us>, art Saltmarsh
<art_saltmarsh@admin.state.ak.us>, Thomas E Maunder <toID_maunder@admin.state.ak.us>
There is something I didn't get around to before I left and that was to administratively amend the cas for
PBU to include reporting dates agreed to verbally with BP (and DNR). Really, only pt. McIntyre and Borealis
have the wrong dates in the eo's. The others are either ok, or not explicit. Attached are the COs affected.
I'm not sure how you want to handle. Jody. Please put this in the following CO files along with the
attachment.
Group I - IP A Oil Pools
Prudhoe Oil Pool C0341D
Put River Oil Pool C0559
Group 2 ~ GPMA Oil Pools
Lisburne C0207, 207 A
Niakuk C0329A Rule 9
North Prudhoe Bay C0345
Pt. McIntyre C0317B
Raven Oil Pool C0570
West Beach Oil Pool C0311B
Group 3 - Prudhoe Satellite Oil Pools
Aurora C0457B
Boreallis C0471
Midnight Sun C0452
Orion C0505A
Polaris C0484A
-------- Original Message --------
Subject:Re: surveillance report dates
Date:Thu, 31 Aug 2006 17:27:45 -0800
From:Jane Williamson <iane williamson(a!admin.state.ak.us>
Organization:State of Alaska
To:Lenig, David C <David.Lenig(Cl?bp.com>
References:<CBF4D8E92B5A 70479F64416582F6A 17CB81 AEO(a!bp 1 ancex005.bp 1.ad.bp.com>
Oops
Lenig, David C wrote:
Hi Jane,
100
4/23/2007 9:50 AM
LA ..-. LA ,..... .."-....~.............. . ""'-'-""-....--..... ..-t'.......-'-... -.........uJJ
.
.
didn't get the attachrnent
David
From: Jane Williamson
Sent: Thursday, August 31, 2006 5: 14 PM
To: Lenig, David C
Subject: Re: surveillance report dates
E-mail is fine.
Attached is a list of the pools and orders/rules that will be amended with the Admin approval. Take a look and
see if this looks right to you. (Note, I'm only listing the rules that are affected by the new dates - there may be
additional amendments unrelated to the surveillance requirements that I've not listed.)
I'm flexible on the date for the Overview presentation. I'd be fine with specifying it to be within one or two months
of the report date rather than the POD overview that you've noted. What would you prefer?
Lenig, David C wrote:
Jane,
Here is a table showing the dates for the various Reports and
Presentations. I've added the production period as well. The IPA review
date remains problematic due to the proximity to spring break but we
seem to work around it each year.
Would you prefer that I put this in a letter requesting the changes? I
know we talked about this a little while ago I just haven't found the
time.
Thanks,
David
Plan of Development
Production Period
Jull-Jun30
IPA GPMA
March 15 June 15 September 15
March 22 June 22 September 22
March 30 June 30 September 30
Janl-Dec31 Aprl-Mar31
Satellites
Annual Surveillance Report
Annual Overview Presentation
-----Original Message-----
From: Jane Williamson [mailto:jane williamson@ad~in.state.ak.us]
Sent: Thursday, August 31, 2006 2:30 PM
To: Lenig, David C
Subject: surveillance report dates
Hi David.
When you get a second, could you please send back an e-mail that lists
all the surveillance report dates that we've agreed to for all PBU pools
(including GPMA)? Also, do you have dates for surveillance reviews?
I'll go through the list and make sure the Conservation orders are
correctly worded, then put out administrative amendments as necessary.
I checked with Cammy and she said an e-mail is fine for starting the
20f3
4/23/2007 9:50 AM
l' ..-. L"'- ........ -"-~_......-... ............-.....-.... ~-r.......... --..-.....JJ
.
administrative action process.
.
Thanks.
Jane "\JVi Hian1S0Rl"
<i ane ,,;.villiaD.lsorl(~adT(liTl. state. alc. us>
Senior Reservoir Engineer (907) 793-1226
Alaska Oil and Gas Conservation Commission
Content-Type: application/vnd.ms-excel
surveillance report.xls
Content-Encoding: base64
3 on
4/23/2007 9:50 AM
*5
[Fwd: Re: Request Surveillance reporting peri.arificatiOn]
.
!
Subject: [Fwd: Re: Request Surveillance reporting period clarification]
From: Jane Williamson <jane _ williamson@admin.state.ak.us>
Date: Thu, 31 Aug 2006 13:37:23 -0800
To: Jody J Colombie <jody_colombie@admin.state.ak.us>
CC: Cathy P Foerster <cathy_foerster@admin.state.ak.us>, Camille
<cammy _ taylor@law.state.ak.us>
Please put this e-mail in the CQ 505a and C0484A files.
-------- Original Message --------
Subject:Re: Request Surveillance reporting period clarification
Date:Thu, 31 Aug 200613:33:53 -0800
From:Jane Williamson <jane williamson(a!admin.state.ak.us>
Organization:State of Alaska
To:West, Taylor <Taylor.West(a!bp.com>
CC:Sullivan, Claire (Claire.Sullivan(a!BP.com) <Claire.Sullivan(2~bp.com>, Bajsarowicz,
Caroline J <Caroline.Bajsarowicz(a!bp.com>, Holloway, Emberley L
<Emberley.Holloway(a!bp.com>, Lenig, David C <David.Lenig(a!bp.com>
References:<C I1D74A5F 1 DF 194DB3A9ADF 4DBC4EDEOC9B99D(a!bp lancex005.bp l.ad.bp.com>
Taylor,
Yes, both reports will be due on September 15 each year, and both reports for this year should cover July
1, 2005-June 30, 2006. The requirement to report on the period from January 2005-June 2006 was in
error as you had provided that information in last years report.
Thanks so much for bringing this to my attention.
Jane
West, Taylor wrote:
10f2
8/31/20062:03 PM
[Fwd: Re: Request Surveillance reporting peri.arificatiOn]
.
.
I
Jane:
"
Per our phone conversation today, I would like Commission clarification on two annual surveillance
report requirements:
1. Orion (CO 505A) Rule 9 states: "An annual report must be filed by September 15... .must include...
surveillance information for the period July 1 of the prior calendar year through June 30 of the current
calendar year (except the report due on September 15.2006 must cover the period from January
2005 through June 30. 2006)"
The last Orion Surveillance report submitted to the Commission on September 15, 2005 covered the
period September 1, 2004 through July 31, 2005.
Would it be acceptable for the current report to cover the period July 1. 2005 through June 30.
2006? This will keep Orion aligned with the other satellite assets, and will actually provide a one month
(July 2005) overlap with last year's report. It's not clear to me if there is value in restating the Jan 2005
through June 2005 data in the current report.
2. Polaris (CO 484A) Rule 9 contains the historic reporting language: "The report (covers)... the prior
calendar year".
Please confirm that the current report should cover the period July 1. 2005 through June 30. 2006 per
prior conversations, and in keeping all satellite assets aligned. As with Orion, the current report will
overlap last year's report by one month.
Thanks
Taylor West
Production Engineer
BP Exploration (Alaska), Inc.
Greater Prudhoe Bay - Polaris I Orion Viscous Oil
907.564.4647
907.632.0111 cell
907.564.5016 (fax)
WestTL~bp.com
Jane Williamson, PE <jane wilIiamson(a!admin.state.ak.us>
Senior Reservoir Engineer (907) 793-1226
Alaska Oil and Gas Conservation Commission
20f2
8/31/20062:03 PM
#4
RE: Hearing vacated
.
.
Subject: RE: Hearing vacated
From: "Paskvan, Frank A" <Frank.Paskvan@bp.com>
Date: Thu, 30 Mar 2006 15:25:45 -0900
lliamson <j illiamson
illi >, "SuI
" <Gary.
ould@bp.co
CC: J J Colombie
<bob _ crandall@admin.
Jane,
Thank you very much for the update i.e. Orion AIO mod hearing
vacated. If any outstanding questions arise, please let us know. RE
item IV-4 confidentiality, 2 years is sufficient.
As an FYI, you probably already know this, but we're in the process of
GC-2 production restart. You may notice in well production that
actually already a couple of Kuparuk sats wells alreadly are being
flowed now. These are to slowly warmup production pipelines prior to
full restart. Their production is routed into GC-l, not GC-2, for
processing. MI and Water injection has been continued at GC-2 although
at a lower than typical levels since we don't have GC-2 produced water
to inject. Injection water comes from GC-1 via waterwheel. We're
warming up the gas lift system by bullheading gas into an Orion and
Polaris producer. We might see GC-2 itself processing oil as early as
Sunday, but expect it will be some time before full capacity is
restored. . .
Regards,
Frank Paskvan
-----Original Message-----
From: Jane Williamson [mailto:jane williamson@admin.state.ak.us]
Sent: Wednesday, March 29, 2006 11:41 AM
To: Paskvan, Frank A¡ Williams, Jonathan 0
Cc: Jody J Colombie¡ Robert P Crandall
Subject: Hearing vacated
Frank and Jonathon,
The hearing on Orion is vacated.
One item we need for our records. How long are you requesting IV-4 to
be held confidential?
Jane
1 of 1 3/30/20063:37 PM
#3
Hearing vacated
~
.
Subject: Hearing vacated
From: Jane Williamson <jane _ williamson@admin.state.akus>
Date: Wed, 29 Mar 2006 11 :41:00 -0900
FrankA" <Pask
Frank and Jonathon,
The hearing on Orion is vacated.
One item we need for our records. How long are you requesting IV-4 to be held
confidential?
Jane
Jane Williamson, PE <iane williamson(Q}admin.state.ak.us>
Reservoir Engineer
Alaska Oil and Gas Conservation Commission
1 of 1
3/29/20061:15 PM
#2
---------..----
STATE OF ALASKA . NOTICE TO PUBLISHER . ADVERTISING ORDER NO.
ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING AOVERTISING ORDER NO., CERTIFIED AO-02614029
AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF
ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE
SEE BOTTOM FORINYOICEADDRESS
·c
F AOGCC AGENCY CONTACT DATE OF A.O.
R 333 W 7th Ave, Ste 100 Jodv Colombie March 1, 2006
0 Anchorage, AK 99501 PHONE PCN
M - (907) 791 -1221
DATES ADVERTISEMENT REQUIRED:
T Anchorage Daily News March 2, 2006
0
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ENTIRETY ON THE DATES SHOWN.
SPECIAL INSTRUCTIONS:
Advertisement to be published was e-mailed
Type of Advertisement legal~ 0 Display Classified DOther (Specify)
SEE ATTACHED
SENDIN\1()I~l:l~T~F'l..lp~TEI AOGCC, 333 W. 7th Ave., Suite 100 I TOTAL OF ¡I
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1 05 02140100 73451
2
3
4 ,~ i/' / I~
I
REQUISITI~~~Ã__ ( (tJËJw\ / "'. DIVISION APPROVAL:
i ) '-
!
\/
.
.
Notice of Public Hearing
STATE OF ALASKA
Alaska Oil and Gas Conservation Commission
Re: Prudhoe Bay Field
Orion Oil Pool
Application to amend Area Injection Order 26 and Conservation Order 505
By application dated February 23, 2006, BP Exploration (Alaska) Inc. as Unit Operator
of the Prudhoe Bay Unit requested the Commission to amend Area Injection Order 26 and
Conservation Order 505 to authorize underground injection of enriched gas into the Orion Oil
Pool. The Orion Oil Pool of the Prudhoe Bay Field lies within Tl2N-RIOE, Tl2N-RllE, TllN-
RIlE, Tl1N-RI2E, Umiat Meridian.
The Commission has tentatively scheduled a public hearing on this application for April
6, 2006 at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission at 333
West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively
scheduled hearing be held by filing a written request with the Commission no later than 4:30 pm
on March 17,2006.
If a request for a hearing is not timely filed, the Commission may consider the issuance
of an order without a hearing. To learn if the Commission will hold the public hearing, please
call 793-1221 after March 24, 2006.
In addition, a person may submit a written protest or written comments regarding this
application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West 7th
Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later
than 4:30 pm on April 3, 2006 except that if the Commission decides. to hold a public hearing,
protests or comments must be received no later than the conclusion of the April 6, 2006 hearing.
ho may need special accommodations in order to
e contact the Commission's Special Assistant Jody
Published Date: March 2, 2006
AO # 02614029
.
Anchorage Daily News
Affidavit of Publication
.
1001 Northway Drive. Anchorage, AK 99508
PRICE OTHER OTHER OTHER OTHER OTHER ~
AD# DATE PO ACCOUNT PElt DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL
735823 03/02/2006 02614029 STOF0330 $186.44
$186.44 $0.00 $0.00 $0.00 $0.00 $0.00 $186.44
. Notice of Public Hearing
STATE OF ALASKA
Alaska Oil and Gas Conservation Commission
Re: Prudhoe Bay Field
Orion Oil Pool
Application to amend Area I niectian
Order 26 and Conservation Order 505
By application dated February 23, 2006, BP Explo-
ration (Alaska) Inc. as Unit Operator of the Prud-
hoe Bay Unit requested the Commission to amend
Area Iniection Order 26 and Conservation Order
505 toauthori.¡;e underground iniectionof enriched
gaS into the Orion Oil Pool. The Orion Oil Pool of
the Prudhoe Bay Field lies within Tl2N·Rl0E,
Tl2N-RllE, TlIN-RllE, TllN-RI2E, Umiat Merid-
ian.
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
Christine Clark, being first duly sworn on oath deposes and
says that she is an advertising representative of the Anchorage
Daily News, a daily newspaper.
That said newspaper has been approved by the Third Judicial
Court, Anchorage, Alaska, and it now and has been published in
the English language continually as a daily newspaper in
Anchorage, Alaska, and it is now and during all said time was
printed in an office maintained at the aforesaid place of
publication of said newspaper. That the annexed is a copy of an
advertisement as it was published in regular issues (and not in
supplemental form) of said newspaper on the above dates and
that such newspaper was regularly distributed to its subscribers
during all of said period. That the full amount of the fee charged
for the foregoing u ication is not in excess of the rate charged
private individua
m(U /~
~,
Joo!t
The Commission has tentativelysèheduled a pub-
lic hearing on this applicatløn' and the Commission
~f~h~s~II~~k:g~11 a6~J~tsa:::~~é~~t~b~~( %r;rs~
sion at 333 West 7th Avenue, Suite 100, Ancharage,
"'Ioska 99501. A person mov request that the tel1to-
tivelv scheduled hearing be held by fllin ¡ èt wrlt-
.ten request with the Commission no loter than 4::30
pm on Morch 17, 2006.
If 0 request for a hearing is not timelv filed, the
'Commission may consider the issuonce of anor-
der without a hearing. To learn if the Commission
will hold the public hearing, please call 793-1221 af-
ter March 24, 2006.
In addition, a person mav submit a written protest
or written comments regarding this application
and Proposal to the Alaska Oil and Gas Conserva·
tion Commission at 333 West 7th Avenue, Suite 100,
Anchorage, Alaska 99501. Protests and comments
must be received no later than 4:30 pm on April 3,
2006 except that if the Commission decides to hold
a public hearing, protests or comments must be
received no later than the conclusion of the April 6,
2006 hearing.
If vou are a person with a disabi¡itvwtK/J.may need
special accommodations in ordef-to, comment or to
attend the public hearing, pleaáec'òntact the
Commission'.s Special Assistant"J!1dy,Calombie at
793-1221. "
Is/: John K. Norman
Chairman
Si
Notary Public in and for the State of Alaska.
Third Division. Anchorage, Alaska
AO #02614029
Published Date: March 2, 2006
Re: Public Notice
.
.
Subject: Re: Public Notice
From: "Ads, Legal" <legalads@adn.com>
Date: Wed, 01 Mar 2006 15:16:08 -0900
To: Jody Colombie <jody_colombie@admin.state.ak.us>
Hello Jody:
Following is the confirmation information on your legal notice. Please
review and let me know if you have any questions or need additional
information.
Account Number: STOF 0330
Legal Ad Number: 735823
Publication Date(s): March 2, 2006
Your Reference or PO#: 02614029
Cost of Legal Notice: $186.44
Thank You,
Kim Kirby
Anchorage Daily News
Legal Classified Representative
E-Mail: legalads@adn.com
Phone: (907) 257-4296
Fax: (907) 279-8170
On 3/1/06 9:38 AM, "Jody Colombie" <jody colombie@admin.state.ak.us> wrote:
Please publish tomorrow.
Jody Colombie
Special Staff Assistant
1 of 1
3/1/2006 3 :31 PM
02-902 (Rev. 3/94)
Publisherl riginal Copies: Department Fiscal, Departme , eceiving
AO.FRM
STATE OF ALASKA
ADVERTISING
ORDER
$EEBOTTOM FOR]NVOICEADDRESS
NOTICE TO PUBLISHER
ADVERTISING ORDER NO.
INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED
AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF
AOVERTISEMENT MUST BE SUBMITTED WITH INVOICE
AO-02614029
F
R
o
M
AOGCC
333 West ih Avenue. Suite 100
Anr.hnr::tup A K QQ~Ol
907-793-1221
AGENCY CONTACT
.Indv ~ .
PHONE
(907) 791 -1221
DATES ADVERTISEMENT REQUIRED:
DATE OF A.O.
I M::tTrh 1 2006
PCN
T
o
Anchorage Daily News
PO box 149001
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March 2, 2006
THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS
ENTIRETY ON THE DATES SHOWN.
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Account # STOF0330
United states of America
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division.
Before me, the undersigned, a notary public this day personally appeared
who, being first duly sworn, according to law, says that
helshe is the
of
Published at
in said division
and
state of
and that the advertisement, of which the annexed
is a true copy, was published in said publication on the
day of
2005, and thereafter for _ consecutive days, the last
publication appearing on the _ day of
. 2005, and that
the rate charged thereon is not in excess of the rate charged private
individuals.
Subscribed and sworn to before me
This _ day of
2005,
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My commission expires
Mary Jones
XTO Energy, Inc.
Cartography
810 Houston Street, Ste 2000
Ft. Worth, TX 76102-6298
George Vaught, Jr.
PO Box 13557
Denver, CO 80201-3557
John Levorsen
200 North 3rd Street, #1202
Boise, ID 83702
Michael Parks
Marple's Business Newsletter
117 West Mercer St, Ste 200
Seattle, WA 98119-3960
Ciri
Land Department
PO Box 93330
Anchorage, AK 99503
Jill Schneider
US Geological Survey
4200 University Dr.
Anchorage, AK 99508
Darwin Waldsmith
PO Box 39309
Ninilchick, AK 99639
Penny Vadla
399 West Riverview Avenue
Soldotna, AK 99669-7714
Bernie Karl
K&K Recycling Inc.
PO Box 58055
Fairbanks, AK 99711
.
David McCaleb
IHS Energy Group
GEPS
5333 Westheimer, Ste 100
Houston, TX 77056
Jerry Hodgden
Hodgden Oil Company
408 18th Street
Golden, CO 80401-2433
Kay Munger
Munger Oil Information Service, Inc
PO Box 45738
Los Angeles, CA 90045-0738
Mark Wedman
Halliburton
6900 Arctic Blvd.
Anchorage, AK 99502
Baker Oil Tools
4730 Business Park Blvd., #44
Anchorage, AK 99503
Gordon Severson
3201 Westmar Cr.
Anchorage, AK 99508-4336
James Gibbs
PO Box 1597
Soldotna, AK 99669
Richard Wagner
PO Box 60868
Fairbanks, AK 99706
North Slope Borough
PO Box 69
Barrow, AK 99723
.
Mona Dickens
Tesoro Refining and Marketing Co.
Supply & Distribution
300 Concord Plaza Drive
San Antonio, TX 78216
Richard Neahring
NRG Associates
President
PO Box 1655
Colorado Springs, CO 80901
Samuel Van Vactor
Economic Insight Inc.
3004 SW First Ave.
Portland, OR 97201
Schlumberger
Drilling and Measurements
2525 Gambell Street #400
Anchorage. AK 99503
Ivan Gillian
9649 Musket Bell Cr.#5
Anchorage. AK 99507
Jack Hakkila
PO Box 190083
Anchorage, AK 99519
Kenai National Wildlife Refuge
Refuge Manager
PO Box 2139
Soldotna, AK 99669-2139
Cliff Burglin
PO Box 70131
Fairbanks, AK 99707
Williams Thomas
Arctic Slope Regional Corporation
Land Department
PO Box 129
Barrow, AK 99723
M /\1 \v1o U
ì ( )11 I
Public Notice Prudhoe Bay Field Orion Oil PO'-
.
Subject: Public Notice Prudhoe Bay Field Orion Oil Pool
From: Jody Colombie <jody_colombie@admin.state.ak.us>
Date: Wed, 01 Mar 200609:39:57 -0900
To: undisclosed-recipients:;
BCC: Cynthia B Mciver <br _ er@admin;stá in
<robert mintz ak.us>, Christine Hansen .hansen@iogcc.state. s>,Te
<hub ewman <StewmaSD@BP.com>;Scott & Cammy Tay
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3/1/200610:21 AM
Public Notice Prudhoe Bay Field Orion Oil po,-
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3/1/200610:21 AM
Public Notice
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Subject: Public Notice
From: Jody Colombie <jody _ colombie@admin.state.ak.us>
Date: Wed, 01 Mar 200609:38:11 -0900
To: Legal Ads AnchørâgeDai1y
Please publish tomorrow.
Jody Colombie
Special Staff Assistant
Content-Type: application/msword
Order form.doc
Content-Encoding: base64
Content-Type: application/msword
Orion Public Notice.doc
Content-Encoding: base64
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3/1/2006 10:21 AM
#1
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BP Exploration (Alaska), I.
900 East Benson Boulevard
Post Office Box 196612
Anchorage, Alaska 99519-6612
Telephone (907) 561-5111
.
ObP
February 23, 2006
REceiVED
FEB 2 7 2.006
Alaska Oil & Gas Cons. Commission
Anchorage
Commissioners
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
RE: Modifications to Conservation Order 505 and Area Injection Order 26
Orion Oil Pool - Prudhoe Bay Field
Dear Commissioners:
BP Exploration (Alaska) Inc. (BPXA) , operator of the Prudhoe Bay Unit (PBU), on
behalf of itself and the other the PBU Working Interest Owners, requests
modification of Conservation Order No. 505 (CO 505) and Area Injection Order No.
26 (AIO 26) to allow for the injection of miscible injectant necessary to enhance
recovery from the Orion Oil Pool.
Attached is a detailed description of the proposed CO 505 and AIO 26 modifications.
BPXA also requests that all exhibits labeled "Confidential" be treated as confidential
in accordance with the provisions of AS 31.05.035(d) and 20 AAC 25.537.
Should you have any questions regarding this request, please contact Jonathan
Williams at 564-5854.
Sincerely,
/~ <4L fJ~--
F~~~kvan !
GPB WEST Manager
Attachments
CC:
Sonny Rix, ExxonMobil
Dan Kruse, CPAI
Paul Winslow, Forest Oil
Gary Forsthoff, Chevron
Jonathan Williams, BPXA
Taylor West, BPXA
Gary Gustafson, BPXA
David Lenig, BPXA
Jane Williamson, AOGCC
Art Copoulos, DNR
Application for orion. Injection Order Modification
.
2/23/2006
Modification of
Area Injection Order 26
Orion Oil Pool
February 23, 2006
Area Injection Operations............. ................................. ..................................................... 2
Plat of Project Area......................................................................................................... 2
Operators/Surface Owners .............................................................................................. 2
Description of Operation......................................................................... ........................ 2
Geologic Information.......................................................................................... ............ 3
Mechanical Integrity of Injection Wells ......................................................................... 3
Injection Fluids.................... ....................................... .................................................... 4
Type of Fluid/Source...................... .......... .................................................................. 4
Composition and Compatibility with Formation and Confming Zones ..................... 4
Maximum Injected Rate........ .......................... ............................................................ 4
Injection Pressures.......................................................................................................... 4
Fracture Information........................................................................ ............................... 5
Formation Water Quality ................................................................................................ 5
Fresh Water Strata................................................................ ........ ............................... 5
Hydrocarbon Recovery ......................... ........... ....................................... ........................ 6
Surveillance Plan ................................................... ..................................................... 9
Mechanical Condition of Wells Within a One-quarter Mile Radius of Injectors........... 9
List of Exhibits.................................. ................................................................................ 10
Exhibits
1 of 10
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Application for Orion Area Injection Order Modification
2/23/2006
Area Injection Operations
This application, prepared in accordance with 20 AAC 25.402 (Enhanced Recovery Operations)
and 20 AAC 25.460 (Area Injection Orders), requests modification of Area Injection Order No.
26 at Orion to encompass injection of Prudhoe Bay Miscible Injectant (PBU MI) for enhanced
recovery operations (EOR).
Plat of Project Area
20 AAC 25.402(c)(1)
~xhibit 1-1 shows the general location of the Orion Oil Pool (OOP) and Injection Area and
includes all existing injection wells, production wells, abandoned wells, dry holes, and any other
wells within the OOP as of February 1,2006. Specific approvals for any new injection wells or
existing wells to be converted to injection service will be obtained pursuant to 20 AAC 25.005,
25.280 and 25.507, or any applicable successor regulation.
Operators/Surface Owners
20 AAC 25.402(c)(2) and 20 AAC 25.402(c)(3)
BP Exploration (Alaska) Inc. is the designated operator of the Orion Participating Area. Exhibit
II-I is an affidavit showing that all the Operators and Surface Owners within a one-quarter mile
radius of the injectors within the Orion Participating Area have been provided a copy of this
application.
Description of Operation
20 AAC 25.402(c)(4)
The development plans for the OOP are described in Section II of the OOP application, dated
October 1, 2003, and are updated annually with reports to the commission. The contemplated
operation addressed in this application is a tertiary recovery project using the enhanced oil
recovery (EOR) techniques of miscible gas flooding and viscosity reducing immiscible enriched
gas flooding to increase recoverable oil. The project i~vo1ves the cyclical injection of water
alternating with injection of enriched hydrocarbon gas into the oil column of the Schrader Bluff
sandstone fonnation of the OOP. The gas to be used in the project ("Miscible Injectant" or
"MI") will be comprised of hydrocarbon gas, enriched with intennediate hydrocarbons,
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Application for orion. Injection Order Modification
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2/23/2006
principally ethane and propane.
In a part of the project area where the reservoir oil has sufficient concentration of C7-CI3, the
MI forms a miscible bank with the reservoir oil through the exchange of hydrocarbon
components, and effectively displaces nearly all of the contacted oil, resulting in residual oil
saturations significantly lower than with watertlood alone. The oil develops miscibility with MI
at reserVoir conditions by the condensing-vaporizing multiple contact miscibility mechanism. In
areas of the reservoir (project area) where the biodegradation of oil is high, the oil lacks
sufficient concentration of C7 -C 13 components to be miscible with the PBU MI at reservoir
conditioJ.ls. In this project area, although the injected PBU MI does not develop miscibility with
the reservoir oil in all zones, the multiple-contact condensing/vaporizing mass transfer
mechanism between the CO2 and C2-C4 rich PBU MI and the reservoir oil causes a significant
reduction in the reservoir oil viscosity. The magnitude of tertiary oil recovery by this ''viscosity
reducing, immiscible enriched gas flood" mechanism is in fact very close to the tertiary oil
recovery in the project area with the "miscible gas flood" mechanism. Injected water helps
maintain reservoir pressure, retards gravity segregation of the miscible injectant, and controls gas
channeling.
Orion wells are drilled from the existing Prudhoe Bay Initial Participating Area (IPA) L-Pad, V-
Pad and Z-Pad. Installing a new I-Pad to access the northwest portion of Orion is under
evaluation. MI is currently being delivered to the Orion area through the IP A MI and Borealis
MI pipeline systems. Implementation of the Orion EOR project will involve connection of Orion
injection wells to existing, expanded or new MI trunk and lateral distribution systems on I-Pad,
L-Pad, V-Pad and Z-Pad. First injection ofMI into the OOP is expected to occur in 2Q of2006.
Geologic Information
20 AAC 25.402(c)(6)
The Geology of the OOP is described in Section I of the Pool Rules application.
Mechanical Integrity of Injection Wells
20AAC 25.402 (C) (8)
All Orion wells drilled for injection service have been completed in accordance with 20 AAC
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2/23/20b6
Application for Orion Area Injection Order Modification
25.412, thus satisfying the mechanical integrity requirements as required by 20 AAC 25.402.
The casing program for each well was permitted and completed in accordance with 20 AAC
25.030. Each injector has been on water injection prior to this application, with full commission
witnessed testing prior to being placed on water injection. Prior to startup of MI injection, or as
directed by the commission, current injectors will have a commission witnessed pressure test to
demonstrate the mechanical integrity wellbore and tubular. Exhibit III-l lists the wells currently
utilized for water injection at Orion that will be used for MI injection service.
All drilling and production operations will follow approved operating practices regarding the
presence ofH2S in accordance with 20 AAC 25.065. Actual casing programs are included with
the "Application to Drill" for each. API injection casing specifications are included on each
drilling permit application.
Injection Fluids
20 AAC 25.402(c)(9)
Type of Fluid/Source
The Orion EOR project will utilize Miscible Injectant from the Prudhoe Bay Central Gas
Facility.
Composition and Compatibility with Formation and Confining Zones
The composition of Miscible Injectant planned for injection was shown in Exhibit VI-3 of the
original Polaris AIO application. Miscible gas is a hydrocarbon with similar composition to
reservoir fluids in the OOP therefore no compatibility issues are anticipated with the formation
or confining zones. The composition of GC-2 produced water and compatibility issues were
addressed in the Polaris AIO application.
Maximum Injected Rate
Maximum miscible gas injection requirements at OOP are estimated at 60,000 MSCFD. Water
injection requirements at OOP are estimated at 100,000 to 125,000 bwpd maximum.
Injection Pressures
20 AAC 25.402(c)(lO)
The average manifold surface miscible gas injection pressure for the project is estimated to be
approximately 3000 psi. The maximum surface injection pressure available for the Orion EOR
4 of 10
Application for orion" Injection Order Modification
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2/23/2006
project is estimated to be approximately 3300 psi. The resulting bottom-hole pressure will be
limited by hydraulic pressure losses in the well tubing, with a maximum expected bottom hole
pressure of approximately 4000 psi. Normal injection pressures will be controlled by choking
the MI from the available manifold pressure to control injection rate into the Schrader Bluff
wells.
Fracture Information
20 AAC 25.402(c)(11)
BPXA previously supplied fracture propagation information in the application for Area Injection
Order for the OOP, and in an Application for Amendment to Area Injection Order No. 26 dated
December 8, 2005. Miscible gas and water injection operations at the OOP are expected to be
above the Schrader Bluff Formation parting pressure to enhance injectivity and improve recovery
of oil. Fracture propagation models and fracturing operations for stimulating wells in the OOP
have involved injecting highly viscous fluids at high rates, 10-20 barrels per minute (bpm).
During both actual and simulated cases, the operations have not created net pressures sufficient
to exceed the integrity of the confining layers. Conditions for planned injection will be at lower
rates, less than 10 bpm, and utilize lower viscosity fluids. Miscible gas and water injection
operations will result in lower net pressures, and will not cause fracturing to occur through the
confming layer.
To ensure injection conformance, injection performance will be monitored for each injection
well. Any significant change in injectivity that would indicate injection out of zone will be
followed up with surveillance. The surveillance could include spinner/temperature logs and if
necessary, a tracer survey to determine the location of the injection anomaly.
Formation Water Quality
20 AAC 25.402(c)(12)
The compositions of injection water from GC-2 and OOP connate water were provided in
Exhibit Vl-2 of the original OOP Ala application. The composition of Orion produced water
will be a mixture of connate water and injection water.
Fresh Water Strata
20 AAC 25.402(c)(13)
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Application for Orion Area Injection Order Modification
2/23/2006
Under 20 MC 25.440, Aquifer Exemption Order No. I exempts those portions of freshwater
aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit,
including the entire OOP.
Hydrocarbon Recovery
20 MC 25.402(c)(14)
Estimates for original oil in place ("OOIP") for the Orion accumulation reflect current well
control, stratigraphic and structural interpretation, and rock and fluid properties. The OOP
current estimate of OOIP ranges between 1070 and 1785 MMSTB. The extent of the range of
estimates is due primarily to uncertainty in the OOP structural definition, oil-water contact and
reservoir net pay interval estimates. Estimated associated formation gas in place ranges from 210
to 345 BSCF. Primary and waterflood recovery is estimated at 5-25% of OOIP based on field
performance reservoir modeling and varies based on rock and crude quality.
A three-dimensional geologic and dynamic flow model of the Orion accumulation has been
constructed based on detailed stratigraphic and structural interpretation. This model provides the
bulk reservoir volume, porosity distribution and recovery estimates for the OOP. The model area
encompasses the known extent of the Orion accumulation. The model has 200 feet by 200 feet
(1 acre) cells and is defined vertically with layers 2 feet thick. Faults and structural
juxtapositions are honored in the model through the use of comer point geometry and non-local
grid connections. Water saturations in the reservoir model were established by capillary pressure
equilibrium. Oil water contacts were varied across the pool based on available log data;
Exhibit IV-I shows forecast OOP production and injection. This forecast includes improved
recovery due to water injection and miscible gas injection. Preliminary evaluations indicate that
EOR could yield a net recovery of up to 6% of OOIP where implemented. The MI source is the
PBU MI. The EOR recovery estimates were obtained using an Equation-of-State (EOS)
developed for reservoir fluid from the neighboring Polaris Oil Pool (POP), an analog to the OOP.
Polaris is an excellent analog for Orion as they produce oil of essentially identical composition
and quality from horizontal multi-lateral wells in the same Schrader Bluff formation at similar
conditions of reservoir temperature, pressure, and depth.
A composite surface sample from well W -203 was acquired. The sample was analyzed for
6 of 10
Application for orion. Injection Order Modification
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2/23/2006
extended compositional distribution. Laboratory swell, multiple-contact, and slimtube
experiments were conducted using this sample and the PBU MI. The laboratory data were used
to develop a new Polaris EOS. Exhibit IV -2 shows a fifteen-fold reduction in viscosity of a 40 cp
Schrader Bluff oil by contacting with PBU MI in a single cell multiple-contact laboratory
experiment conducted at reservoir conditions. Exhibits IV-3 and IV-4 show the density and k-
values in the same experiment and Exhibit IV -5 shows recovery at 1.2 PV in a slimtube
experiment with PBU MI. The Exhibits IV -2 through IV -5 also demonstrate a good match of the
laboratory data with the EOS model.
Bottom-hole samples from sands OA, OBa, OBc, and OBd for well W -205 and a composite
OBc-d sample from well W -200 were collected and analyzed for extended compositional
distribution. The compositional analysis illustrated that the W-Pad oil quality was different in
different sands, varying from highly bio-degraded, high viscosity (> 1 00 cp) oil with lower C7-
C 13 concentrations in the OA sands to moderate viscosity (<40cp) oil with higher C7 -C 13
concentrations in the OBc sand. The newly developed Polaris EOS was next used to calculate the
minimum miscibility pressure (MMP) for oil from these sands with PBU MI. The PBU MI was
found to be miscible with the oil from the W200 OBc-d sand at reservoir conditions (MMP 2250
psia). However, the calculated MMP was about 1000 psia higher than the reservoir pressure for
other sands with lower concentrations of the C7 -C 13 components (Exhibit IV -6).
Fully compositional, mechanistic Type Pattern Model (TPM) Simulations were conducted using
the Polaris EOS for a W-Pad reservoir description, and varying oil quality (from miscible OBc
sand oil to high viscosity, below MMP OA sand oil) and 30% HPV slug injection of PBU MI at
WAG ratio of 1. These simulations showed that the incremental oil recovery (WAG -
Waterflood recovery) for the below miscible, but very efficient viscosity reducing WAG flood in
the OA sand was very close to the incremental oil recovery for the miscible WAG flood for the
OBc sand (Exhibit IV -7).
Single-contact PVT experiments and one-dimensional, displacement simulations of varying
quality Schrader Bluff oils with PBU MI explain why the incremental recovery for immiscible,
high viscosity oils is of the same magnitude as the incremental recovery for miscible moderate
viscosity oils. Single-cell, multiple-contact laboratory PVT experiments with a 40 cp Schrader
Bluff W -203 oil and PBU MI (Exhibit IV -2) show that there is a significant reduction of oil
7 of 10
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Application for Orion Area Injection Order Modification
2/23/2006
viscosity by PBU MI at reservoir conditions (2100 psia) even if the MMP is much higher (3400
psia).
The reduction in oil viscosity by the condensing/vaporizing mass transfer process in a one
dimensional slimtube displacement is illustrated by examining the oil and gas properties after a
half pore volume of MI injection for two different oils. As shown in Exhibit N -8, for an
immiscible displacement of high viscosity oils by PBU MI, there is a significant reduction in the
oil viscosity by the multiple-contact condensing/vaporizing mass transfer mechanism by the
enriched PBU MI carrying a high concentration of C02 and C2-C4 components. This multiple
contact, condensing/vaporizing mechanism is essentially the same as the condensing/vaporizing
mechanism in miscible moderate viscosity oils. In both these displacements, the reduction in oil
viscosity by the condensing rich components ftom the gas phase is of the same magnitude. The
only difference is that in the miscible displacement case, the gas phase richness by vaporization
mechanism brings the oil and gas composition close to critical point (K-values becomes 1.0),
further reducing interfacial tension between the gas and oil phase. In these viscous oil
displacement processes, through rich gas injection, the most significant part of the enhanced
recovery results ftom the viscosity reduction and displacement of less viscous oil by water to the
producing well. Further enrichment of the injected gas will achieve miscibility, i.e. the gas and
oil compositions get closer to the critical point and the interfacial tension between the gas and oil
phase is reduced. However, the additional recovery by the miscibility mechanism may not be as
significant in the highly viscous oil displacements.
In summary, displacement mechanism for Orion and Polaris reservoir fluid with PBU MI ranges
ftom multiple-contact miscible for oils with high concentration of C7 -C 13 components to a very
efficient viscosity reducing immiscible (VRI) displacement for oils with lower concentration of
C7-C13 concentration. The EOR recovery estimate for the whole range of varying Polaris oil
compositions is quite close. Assuming a 67% areal sweep, 3D incremental EOR recovery for this
W-Pad description is 10%. To account for a range of reservoir description ftom most favorable
to unfavorable, the EOR recovery was estimated to range ftom 2-10% with average around 6%.
Gross utilization of PBU MI to achieve this EOR recovery was estimated to be around 5.3 MCF
of MIlbarrel of EOR oil. This MI efficiency is similar to MI efficiency at other GPB new EOR
projects (e.g. Aurora and Borealis). The MI efficiency of these new EOR projects is
8 of 10
Application for orion" Injection Order Modification
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2/23/2006
significantly better than the marginal MI efficiency around 15-20 MCF/barrel of EOR oil for
continued injection of MI into the mature IP A EOR project area, thus justifying the preferential
injection of PBU MI into the Orion EOR project area over IP A.
Surveillance Plan
To ensure the efficient allocation ofMI for the Orion EOR project, rate and pressure response to
injection will be monitored. Production fluid compositional samples will be taken at least
annually to assess pattern efficiency based on the returned MI (RMI) ratio. Offset producers of
injectors currently on MI can be sampled on a more frequent basis to help determine break
through times and flood efficiency. Water injection surveillance will continue using pressure
falloffs and other monitoring methods as required by patterns. Injection of water and miscible
gas into patterns will be evaluated on a regular basis to address pattern performance and
optimum injection rates to maximize recovery.
Mechanical Condition of Wells within a One-quarter Mile Radius of Injectors
20 AAC 25.402(c)(15)
A map showing all penetrations through the OOP, and wells within a one-quarter-mile radius of
the injection wells are shown on Exhibit V-I. Mechanical integrity has been established for the
subject wells based on calculated cement tops being at an adequate height above the injection
zone to prevent fluid that is injected into the OOP from flowing into other zones or to the
surface. All existing Orion injection wells have been certified as Service Wells allowing water
injection. Dates for recertification are on file with the AOGCC. Prior to any enhanced injection
on wells without prior certification, wells will be certified through established approved testing
procedures, with a requested State Inspector present, to confirm mechanical integrity as required
by 20 AAC 25.402 (e).
Although injection pressure will exceed average OOP reservoir pressure, reservoir modeling
indicates rapid reservoir pressure falloff away from the injector during water and MI injection.
Reservoir modeling indicates a radius of pressure influence less than 1000 feet from the injector
at the end of the MI cycle.
9 of 10
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Application for Orion Area Injection Order Modification
2/23/2006
List of Exhibits
I-I Orion Pool Rilles and AIO Area
II-I Affidavit
III-1 Orion Injection Wells
IV-lOOP Production and Recovery Profiles with Water and Miscible Gas Injection
IV-2 Viscosity Reduction ofW-203 Oil by Prudhoe Bay MI in a Milltip1e Contact
Experiment
IV-3 Density of Polaris W-203 Oil by Prudhoe Bay MI in a Multiple Contact Experiment
N-4 K-values of Polaris W-203 Oil by Prudhoe Bay MI in a Multiple Contact Experiment
IV-5 W-203 Oil Slimtube Experiment with PBU MI at Reservoir Temperature
IV-6 Minimum Miscibility Pressure Variation with Oil C7-CI3 Concentrations
IV -7 Incremental Oil with Prudhoe Bay MI Injection for Polaris Oil with Medium to High
Viscosity Range
IV -8 Phase Viscosity after 0.5 HPV MI Injection
V-I Orion Injection Area Wells Within 14 mile of Injectors
10 of 10
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Exhibit II-I
AFFIDA VIT
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
I, Frank A. Paskvan, declare and affirm as follows:
1. I am the Greater Prudhoe Bay West Manager for BP Exploration (Alaska) Inc., the
designated operator of the proposed Orion Participating Area, and as such have
responsibility for Orion operations.
2. On h-J. ).1- Z:>c t, , I caused copies of the Orion Area Injection Order Amendment
Application to be provided to the following surface owners and operators of all land
within a quarter mile radius ofthe proposed injection area:
Operators:
BP EXPLORATION (ALASKA), INC.
GREATER PRUDHOE BAY PERFORMANCE UNIT
ATTENTION: MAUREEN JOHNSON
P.O. BOX 196612
ANCHORAGE, AK 99519-6612
Surface Owners:
STATE OF ALASKA
DEPARTMENT OF NATURAL RESOURCES
DIVISION OF MINING, LAND AND WATER
ATTENTION: DICK MYLIUS
550 WEST 7TH AVENUE, SUITE 1070
ANCHORAGE, AK 99501-3510
F;.J.. ~.~ 7- J 'ZC:it) b
.
Dated:
Declared and affirmed before me this ~ day of
~. p~L-
Fr A. Paskvan
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Notary Public in and, r Alaska
My commission expires~\.. )~D ~
Well Name
L-117
V-201
L-103
V-105
L-210
L-211
L-216
V-213
V-216
V-210
V-211
V-221
L-212
L-214
L-218
L-215
V-212
.
Exhibit 111-1
Orion Injection Wells
.
Orion Area Injection Wells in Service, by Spud Date
API No.
500292303900
500292305400
500292310100
500292309700
500292318700
500292319700
500292320600
500292321300
500292321600
500292323100
500292323200
500292324600
500292325200
500292325800
500292327200
500292327400
500292327900
Spud Date
9/13/2001
12/25/2001
7/26/2002
8/27/2002
12/31/2003
2/24/2004
5/2/2004
7/12/2004
9/2/2004
10/31/2004
11/12/2004
2/22/2005
3/23/2005
5/16/2005
8/24/2005
9/08/2005
12/2/2005
Well Type
Commingled Vertical Water Injector
Vertical Water Injector
Commingled Vertical Water Injector
Commingled Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
Vertical Water Injector
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