HomeMy WebLinkAbout1.01 Supplemental Application MaterialsÖ\oLssoN*
ASSOCIATES
March 11,2016
GIenn Hartmann
Garfield County Community Development
108 8th Street, Suite 401
Glenwood Springs, Co 81601
Re Completeness Review Ursa Battlement Mesa PUD Temporary Surface Lines
PDPA-03-16-8429
Dear Glenn:
This letter is provided to you in response to the County's completeness review of the
Ursa Operating Company LLC Battlement Mesa PUD Temporary Surface Lines Special
Use Permit Application located within the Battlement Mesa PUD.
1. Additional authorizations are needed as follows:
. A letter from Steve Rippy authorizing URSA to act on behalf of the District
regarding the Application.
Response: A letter authorizing Ursa to obtain permits on behalf of BMMD for
this pipeline is included in this response.
. A letter from Eric Schmela to authorize URSA to act on behalf of Battlement
Mesa Land lnvestments.
Response: A letter authorizing Ursa to obtain permits on behalf of Battlement
Mesa Land lnvestments for this pipeline is included in this response.
2. Surface Use Agreements for the proposed pipeline uses are needed along with any
associated easements for the pipeline uses.
Response: Surface IJse Agreements between BMMD and Batttement Mesa Land
Investments and Ursa are included in this response.
3. The Application indicates that the adjacent property owner map includes information
on location of buildings and their uses within 350 ft. of the pipeline. An update to the
760 Horizon Drive, Suite 102
Grand Junction, CO 81506
TEL 970.263.7800
FAX 970.263.7456 www.olssonassociates. com
Ursa Battlement Mesa PUD Temporary Surface Lines
March 11,2016
PDPA-o3-16-8429
Page 2
map with appropriate labelling or a written summary is needed outlining information
on buildings and their uses within 350 ft. of the pipeline.
Response: These items are shown on the Adjacent Properties Map in Section 9-
102.F of the original submittal package.
While not a completeness issue, please note that as with the recent Tompkins
Gathering Pipeline additional ínformation will likely be needed regarding your
Hazardous Materials Spill Plans/Responses including information on monitoring of the
pipeline. As the URSA Spill Prevention, Control, and Countermeasure Plan is
referenced in the current Application provisions from that plan may need to be identified
Response: Copies of Ursa's Spill Prevention, Control and Countermeasures Plan
(SPCC) and Spill Prevention and Management Plan are included with this response.
There will be no site specific plan for the pipeline. The SPCC applies to storage tanks
and not to pipelines, although the basic principles of prevention and control may apply
to pipelines. The Spill Prevention and Management Plan lpnlies to all activities where
the potential for a spill or release exrsfs.
As indicated in the Project Description, operations of the pipeline will include 24-hour
personnel to observe, monitor, and record allwater movement. There always will be at
least one person at each end of the line during water transfer activities. The constant
superuision reduces the potential risk of leaks and failures from oçcurring without being
noticed in a timely manner. Every barrel of water that is senf is accounted for at both
ends of the line. Pressures are monitored constantly. Any change in pressure will result
in immediate action to troubleshoot the cause of the pressure change.
Please let us know if you have any further questions regarding this application. Thank
you for your assistance in expediting the approval of the application.
Sincerely,
-TUÅ"- 6,to,*?*
Tilda Evans
Assistant Planner
Attachments Steve Rippy Authorization Letter
Eric Schmela Authorization Letter
Battlement Mesa Metropolitan District SUA
Battlement Mesa Land lnvestments SUA
Spill Prevention and Management Plan
SPCC Prevention, Control and Countermeasures Plan
16-03-1 1_LDVP_PDPA-o3-16-8429 NTC Response.docx
Battlernent Mesa Metro
401Arroyo Drive / Parachute,
p
co
olitan District
81635
Tel: {970128s-90so I Fax: {97t}} 28s-9531
March 9,201,6
Mr. Glenn Hartmänn
Garfield County Community Development
108 8th Street, Suite 401
Glenwood Springs, CO 81601
RE: Agent Authorization
Dear Mr. Härtrnann,
Battlement Mesa Metropolitan Dastrict authorizes Ursa Operating Company, [l.C, lo act on behalf of and
represent in ¡ll m¡tters regardlng the Battlement Mesa PUÐ Temporary Surface Lines related to land
use permitting for Garfield County.
Please contact me if you have any questions,
Sincerely,
Steve Rippy
Representative of Battlement Mesa Metropolitan Ðistrict
970-28s-9050
CC: John Doose, Ursa Operating Company, LLC
* SËTY'ffG THE COM¡IIUNIW *
WATER & WASTE WATER OPERATIONS * ACNVITY CENTER * ASSOCIATION MANAGEMENT
March 9,20t6
Mr. Glenn Hartmann
Garfield County Community Development
108 8'h Street, Suite 401
Glenwood Springs, CO 81601
RE: Agent Authorization
Dear Mr. Hartmann,
Battlement Mesa Land lnvestments, LLC authorizes Ursa Operating Company LLC to act on behalf of and
represent Battlement Mesa Land lnvestments, LLC in all matters regarding the Battlement Mesa PUD
Temporary Surface Line applicalion dated March 2016 related to land use permitting for Garfield
County.
Please contact me if you have any questions.
Sincerely,
Battlement Mesa lnvestment, LLC
'"r- rô-lt
Agent
Battlement Mesa Companies
970,285.9740 Office
97A379.7943 Cell
gsch E rfi la @ battl em qlrtç-l e s a.cq m
www. ursaresources.com (970) 625-9922 Telephone (970) 625-9929 Fax
TEII,I FORA RY EASEMENT AGR EËÍT,I ENT
Thís Temporary Easement Agreement ('!Agreement') is madc eflective thc lst
day of March, 2016 between, uRsA operating cornpany, LLc ("uRsA',) and the
Battlement Mesa Metropotifan Distríct (,.BMMD').
RECITALS
IVHEREAS, BMMD owns portions of the surface of the tract of land located in
Oarfield County, Golorado upon which LIRSA wishes to extend a r€rnporary pipeline ro
provide watÊr to URSA's Monument Ridge F Pad.
IÅ/HEREAS, sueh pipelir¡e ¿nd other facilities ("FACÍLITIËS') shall ínclude, bur
not necessarily be limited to, on€ twelve inch, sDR I I polyethylene lined (S) from
!MMÐ's water system, at a point to be delermined by BMMD extending upand acrûss
that pipeline corridor depicred in Exhibit A {hereafrei.othe property"}.
WHËREAS, such Facilities shall not be buried;
WHEREAS, URSA has advised that the necessary Facilities easement ¡hall
consisl of a 25 foot priñary easement ånd a temFarary 50 foot construstion casement for
the use of URSA for the installation, operation, mainlenance and repairof the Facilities
that will be used to extend water serviEe from BMMD Facilities to ihe Monument Ridge
B Pad.
AGREEMENT
l. tranlçf Ëasement,.qqftlerm. BMMD hereby grãnrs to uRsA a twenty-five (ij)
fcot primary easement and a fifty (50) foot temporary conshruction eâsement én the
'
surface of the property depicted on Exhibit A for the purpose of constructing and
operating the Facilities for a-period beginning on the dnte of execution of thîs Agreement
and extending to and through Deccmber 31, 20t 6.
2, Indemnification. URSA åErees that the usç and occupâncy of thc surface of the
property of ÊMMÐ its guccessors agents and assigns, by URSA, their agents, employees,
contraÇtors, subcontractorl reprssentativeg, agents or assigns, shall be at the sole risk of
URSÅ. URSA hcreby¿grçet to indemni$, defcnd hold harmless BMMD, its employees,
cuslorners, agenls, guestsn Ssccessors and assigns from and against any and all losses,
ggst damages, claims, awards, attorneyns fees, (including BMMÞ'5 attornÊy's fecs and
litigation expe¡sss, provided such fees and expcnses ars reasonable), expenses, demands,judgmelts or liabilities resulting from in¡iuries or death of any person whomsoever, o,
þ:t!t_{*ages, destruction, pollution, hazardous rnateri¡l spills, discharges to any of
BÑ{MD's or any lhird parties property whatsoever caused by URSA's utilization of ne
Property, or by URSAos agents, representativeq contractors, and cmptoyees. Specifically
I
exçepted from URS.¡t's foregoing Índemnhy in favor of BMMD shall be those losses
llfrcred by BMMI (or othei thírd parties) irrut ,r il;ed by the negligen., * aîn orBMMD or BMMD's agçnts, contractors,.iubcontr¡ci9rr, trf**ntatives or assïgns,uRsA turrheragrees rıinoemniry, r,oiã'nur*1.r,.n¿ Jåeîã BMMÞ, ir emproyees,agents, subcontraclors' representatives, î.ulc.esy5 and assigns *om any ¡irtÍiiiïr,¡"1,may be asserled or determined by an individuat, legal entifr county, state or fsderalagencylased upon a vioration ofany of the proviríon, ofcgRcLj; R¿Rd ır¿, rrr*Clean lVater Act cr common law resulting to* tlt"a"l"*
"t inactions of URSA on theproperty.
t .." . ReçlanaÍíon. At the end of the term of this agreemenr, URSA shall remove theFacilities.from the property of BMMD. UR$A ao"riot *ffiare any ground breakingsurface disturbance lnstant to either the consfiruction, operation or.r*oual of theFacilities; plovided howcver, in the event suctr d¡sturbinc"äorr occurt uRsA agree$ tofollow the Reclamation Âgreement Plan attached herero as ri¡¡u¡t B;;rppltr;iìe wi:hreferences tû any part of the Property disturbed ¡y tt-l"yrã or*,* pl"il¡rî¡|, up",, ¡,.
5' lerminatíon' ThisAgrsement shall be ín full force and effect until terminared bymutual agreemenr blsu parties trereto, ry_if gxnirurion as provided h naragr;ph r¡bove or written notification received Uv ÛnSA' fto'* *r* npfit¡D rhat the BMMD wishesto terminarç such water service or as is othcrwise provi¿ei uyñ.---'
E'! v""r4v 'r
6' . F4þrcerqenl: Snecific Performance. In an event of r¡aterial failure by any of theparties hereto to comply w¡ttr ttri tenns ortnis ngreement, tir* ottrrrpurty *1,äf ri.u*standinglo bring suit to enforqc compliance heriwittr. ru*n*r.ur", in the event of abreach.of this-agreement, the non-breaching party may seek all remedies available at lawor equity, including specific performance. .
7. RqcBrdiUg. Tlris .Àgreemenr shall not be recorded,
I' Att$rnçv'e Fees. Irr the event lÍtigation is necessary to enforce rhe rightl of thcP."tli:r to this Ag:eemenr, as berween thãmselves¡f,rïäí.1ìf.! p*, in such litigarionshall be entitled to attorney's, paralegals, legal ur*iulunr" rees, åosts and expensesincluded in that action.
9' cpunterpgrtqac$r,njlç $iFntIures. Ttis Agreemenr mäy be executed in one ormoreçountel¡afls, all of whish shall constitute a singte ugr*em.nt ¡nd each of whistshall be an original for fll pury?:!s: It is agreed andindeîsmoå that trtr signuiug or*,*parties on a copy hereof transmitted by faisimite shatl be zufncient as if an original.
l0' Nofic.es-.Any notice or othe¡ communication required or permi*ed under thisÁgreement shall be sufficient if deposited in.the u.$. ri"ii, p*ãe" prepaid, or senr viaexpedited delivery service, with proof of delivery, or uy nåJ¡*itr rånri*t iun *iirr''proof of receipt by rhe notifìed purty, addressed äi rorú*r, - '
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Notice to:Steve Rippy, Manager
Battlement Mesa Metropotitan District
401 Anoyo Drive ,
Battlement Mesa, CO g1635
srifipvaltacsol.ne!
trVith copy tol Matthew R. Dalton, Esq.
Grimshaw & Harring, Esq.
I700 Lincoln Street, Su¡te 3900
Denver, CO 80203
m@sri mshawharriq e. cp.n
Notise to:URSA Operating Company, LLC
ATTN: John Doose
792 Buckhorn Drive
Rifle, CO 81650
With Copy to:Ursa Operating Company LLC
ATTN: Janed McGhee
1050 ¡ ?rh Street, Suite 2400
Denver, C0 80202
lN Iù/ITNESS IVHEREOF, parties have executed this Agreement and multipleoriginals reflecting the date set fortli above.
URSA Operating , LLC
By
,tr r f,{- '" eÅ - f *J,*.*<Title:
BATTLEMËNT MESA METROPOLITAN
DISTRICT
By:
Title:J-4,g
3
ffiwF$ffi:..i,,Msnurnent Ridge BFnEsh Water Sourceùffi4#t'Þ.',.i@ÊFø1¡¡Authot: K lVastenda,{tal.ê: 2t23f2?16eV Approximate Waterline iSchernatic)Exiating We[ padBâUlemÊnt Mosa pUÐLegenCç1:J9.aE}G{IBIT A{r ,*51;¡.' r': l- .j'r's;:,r'd'*r-,;i,'Í,,IÈ¡Í, "raÉ'r ú+ t'"&iôìk,'ill¿å!turpj$ñt.teËñjF$i,ÐTgüßs*li'JTFs"?tf ..wal'¡,""fF.tiì,{s.F.la¡..-!v*:¡!r,ilr,ir' ,r1* .,.-" ; l''. 1 ,- .. ,.r.é¡- q," .ú rs¡:t"I"'{IFI"¡.+:.t¡i"f" r: r:r:esy o! fJÈü$ffTÂåterAccess pointZone B Water Tank
Grantor:
Grantee:
ME]TIORANDUM OF
TEMPORARV EASEMENT AGREEMENT
Battlement Mesa Land Investments, LLC, a Colorado limited
liability company, whose address ¡s 73 G Sipprelle Drive,
Battlement Mesa Colorado 81635 ("Grantor"),
Ursa Operating Company LLC, a Delaware limited liability
company, whose address is 1050 17th Street, Suite 24OO,
Denver, Colorado 80265 ("Grantee").
Lands Tnnrnchin ? Qnr ¡fh Þannp QE Wect Âth Þ M
Section t7: S/2
Garfield County, Colorado
Date: March 10, 2016
Summaryr The Grantor owns the surface of a tract in the above described
lands located in Garfield County, Colorado, and, for and in
consideration of payments detailed in the Agreement and other
good and valuable consideration, has granted to Grantee a
temporary easement across the Lands, approximately depicted
on Exhibit A attached hereto and made part hereof by reference,
for the sole purpose of placing a temporary pipeline to facilitate
transportätion of produced water between Granteeb Yater Pad
and the Monument Ridge B Pad.
Copíes of the Agreement and all of the terms and covenants
provided therein are in the possession of both Grantor and
Grantee.
REMAINDER OF TH]S PAGE INTENTIONALLY LEFT BLANK
Page I of 5
GRANTOR:
BATTLEMEUT Mrsn Lnno [NvEsrMËNTs, LLC
a Colorado limlted liabllity company
3-11d6
Eric Schmela
Authorized Agent
GRANTËE:
URsl Open¡r¡uc CoMPANv LLC,
a Þelaware limited liability company
I
Don Simpson
Vice President of Business Development
Page 2 of 5
ACKNOWLEDGMENTS
STATE OF COLORADO
COUNTY OF GARFTELD
The foregoing instrument is acknowledged before me, a notary public,
this
-
day of March, 20L6, by Eric Schmela, as the Authorized Agent for
Battlement Mesa Land Investments, a Colorado limited liability company, on
behalf of the company.
Witness my hand and official seal.
My commlssion expires:
Notary Public
STATE OF COLORADO
CITY AND
COUNTY OF DENVER
The foregoing instrument is acknowledged before mef a notary public,
this _ day of March, 2AL6, by Don Simpson as Vice President of Business
Development for Ursa Operating Company LLC, a Delaware limited liability
company, on behalf of the company.
Witness my hand and official seal.
My commission expires:
Notary Public
)
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)
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ss
ss.
Page 3 of 5
Exhibit A
Attached to and made part of that ceftain Temporary Easement Agreement,
dated this 10th day of March, 20L6, by and between Battlement Mesa Land
Investments, LLC, a Colorado limited liability company, as Grantor, and Ursa
Operating Company LLC, a Þelaware limited liability company, as Grantee
Ðescrlption of the Lands:
Township-7-Sgl¡th,.Bance 95 West,,6tl P.M.
Section L7: S/2
Garfield County, Colòrado
ExhÌbit A continues on the next page
Page 4 of 5
1¡o(oo(¡oI('tâ.ßOo{ f WegendolÐaf*.3'ít"'?0:sffiFunsaBattlement Mesa PU DTemporary Surface LineEATTLÉ¡,4ENT I,4 ESA L.AND INVESTI.,IFN TS'ì,------::----$* I.\rLegend .{ f asem€nt AÊcess i-ocarrons- * , Temporary Recycled lVater L,neBattlement t,îesa PUD BoundaryExhibit A*LIì,li-3-i.:, , .¡.-I-1IIItfli;k*"1":¡.*,-ó-**,,tlAïr r"þfËM'!\tËsAI. ND INV'ES.TTITh,NTSIIIlç,.ti,1.:' ' : ''¡"(t:¡"YAÎERFAD,ñ,ti:t...jf .iue .:!-: iË3r r' !-,-\Lì! t:ì¡r {¡s',iriTemporary Recycled Water LineApprox. 3,980 ftExisting CulvertÊxisting Culvert
ffiursa , rft-,Fll,4lll',1Ç( À¡Ë,At\iY
Colomdo Operations
792 Buckhorn Dr.
Rifle, Co 81650
SPILL PREVE,NTION
ANI)
MANAGEMENT PLAN
Colorado Operations
Piceance Basin
Garfield County, CO
April 2013
Rev #: 3 (February 2016)
ffiUrsa:8åïiffli*r
Colorado Operations
792 Buckhom Dr.
Rifle, CO 81650
SPILL PRE,VENTION
MANAGE,ME,NT PLAI{
Colorado Operations
Piceance Basin
Garfield County, CO
April 2013
Rev #: 3 (February 2016)
ANI)
@trssJ
Prepared by:
HRL Compliance Solutions, Inc.
2385 F % Road
Grand Junction, CO 81505
lt.
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V.
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Contents
Spill Prevention and Response Policy
Purpose and Scope...
Plan Applicability............
Contra ctor a nd Subco ntractor Requi rements a nd Expectations..
Spill/Release Prevention
Spill Management...........
Discovery....
Containment..................
Notification ( U rsa/Contracto rs)
Response....
Agency Notifications & Reporting
Remediation
Waste Management .......................
Training ........
,.4
..5
..5
..5
..6
..6
..6
..7
..7
..8
..9
10
L0
10
10
1.L
A.
B.
c.
D
E.
F.
G
vil.
vilt.
vilil
Spill/Release Costs and lnvoicing..
Spill Response and Remediation Tracking
Appendices
Appendix A
Spill Notification & Management Protocol
Appendix B
Ursa Spill Management Protocol
Appendix C
Environmental Spill/Release Investigation Form
Appendix D
Colorado and Federal Verbal Notification & Written Reporting Information
Appendix D.l
Agency Notification Contact Information
L Spilt Prevention and Response Policy
This plan complements the Ursa Environmental Health & Safety (EH&S) policy and will be used in conjunction
with any site-specific emergency response plans (ERP), if available. All Ursa employees, contractors and
subcontractors will use best management practices (BMPs) to avoid and/or minimize the potential for spills and
releases of substances, chemicals and waste to the environment. BMPs include, but are not limited to the
development and implementation of training, practices and actions that reduce the potential for spills and
releases on federal, state or private lands or roads and properties that are leased, managed, owned, or otherwise
used by Ursa. This plan compliments and addresses spills not specifically addressed under the Ursa's Spill
Prevention Control and Counterïneasure (SPCC) Plan. See SPCC plan for requirements associated with spills
under 40 CFR I 12. This plan is not intended to support or address any policies or existing releases under Antero
Resources Piceance Corporation ownership prior to March 3I, 2013. This plan is intended to support the
business model of URSA Operating Company LLC as of April I,2013.
In the event that a spill or release does occur, ANY volume will be reported to the immediate supervisor and
the appropriate Ursa lead as outlined in Appendix A and managed in accordance with this plan, as well as
Federal and state regulations
It is Uras's internal policy that all releases be reported to the appropriate on-site supervisor and operations lead,
regardless of volume, for internal tracking and trend analysis.
Ursa's Internal Spill Reporting Thresholds
Anv spill that occurs inside or outside permitted work areas or limits of
disturbance/lease boundary.
Any spitl related to transportation while on an Ursa lease or during
transportation of Ursa owned materials/waste.
o
a
Agency Reporting Th resholds
a Anv spill that impacts or threatens to impact live water, wetlands,
drainages, springs or seeps, residence, livestocko etc.
Anv spillof E&P material within permitted work areas of I bbl or
greater outside of secondary containment.
Any spill of E&P material within permitted work areas of 5 bbls or
greater within secondary containment.
Anv spill of Non-E&P hydrocarbon related waste material greater than
25 gallons.
Any spill that exceeds the reportable quantity (RQ) as outlined by the
materials SDS (MSDS) and/or EPA regulated materials.
a
a
a
o
If you are unable to contact the designated Ursa personnel listed in
(APPENDIX A), contact the appropriate Ursa Spill Coordinator (HCSI) so
that any necessary notification or reporting may be completed within the
appropriate reporting time.
il. Purpose and Scope
The purpose of this plan is to provide guidance and expectations for Ursa employees, contractors, and
subcontractors to manager, prevent, and mitigate spills and releases. Spill management includes discovery,
notifications, response actions, reporting, and subsequent remedial actions (as applicable). Ursa management
and employees supervising natural gas exploration and development field activities, including contractor
activities, are expected to have a working knowledge of this plan.
III. PIan Applicabilify
This plan is applicable to all aspects of Ursa's operations including, but not limited to, construction, drilling,
completion, production, and related transportation activities. It is specifically applicable to any vehicles,
facilities, and equipment that use, store, transport, dispose, or otherwise handle or manage chemicals (MSDS-
regulated chemicals), hazardous materials, E&P wastes (drilling muds, produced water, condensate), domestic
waste (septic holding tanks), hazardous waste (acids), extremely hazardous substances, or any other federal or
state regulated substance or waste.
IV. Contractor and Subcontractor Requirements and Expectations
Ursa will not assume administrative, financial, civil, or criminal liability for contractor or subcontractor spills
and releases. Therefore, contractors and subcontractors are strongly encouraged to develop and implement
their own spill prevention and response plans, and spill response capabilities consistent with the objectives of
this plan. The plan and capabilities should be based on the scope of activities as described in their Ursa Master
Service Agreement (MSA). Contractors and subcontractors may use this plan as a guide to develop individual
plans.
In the event ofa contractor or subcontractor spill or release, Ursa actions are to ensure that no current or future
liability exists. Therefore, contractors and subcontractors are expected to fully cooperate with Ursa employees,
designated representatives, and agency officials in any related investigations, management of spill reporting,
and subsequent corrective actions.
Certain spills/release, depending on the volume and material released may require regulatory agency
notification within 24 hours of the release. A release/spill of Ursa owned waste, or a release/spill that occurs
on an Ursa lease that requires regulatory agency notif,rcation, will be completed by Ursa's spill response
program lead or representative. It should be noted that all verbal and written reporting requirements for
contractor releases will be billed to the contractor responsible for the spill/release.
V. SpitVReleasePrevention
lJrsa's first and foremost priority is that it's employees and contractors take all reasonable measures and
implement BMPs to prevent both stationary and transportation-related spills and releases from occurring.
Proactive measures and BMPs include, but are not limited to the following:
avoid potential spill situations such as:
' Checking for open or secured valves prior to, during, and after loading/unloading operations
and facility start-ups;
' Visually monitoring tank levels (don't rely on alarms);
. Constructing berms around loading/unloading areas, or use portable containment;
. Gaskets/Sealingassemblies;
. Checking equipment (tanks, hoses, valves) for deterioration and leaks;
. Servicing vehicles/equipment (oil changes, lubrication) responsibly;
. Operating and maintaining vehicles to avoid accidents resulting in spills;
' Being aware of surroundings when backing or moving vehicles;
. Ensuring stable ground when transporting or placing materials, equipment, tanks, and
pipelines;
personnel on how to avoid potential spill situations and newly implemented rules & regulations.
(i.e. well pads).
VI. Spill Management
For purposes of this plan, spill response and management addresses the major steps listed below. Spill response
is initiated using the Spill Notification and Management Protocol (Appendix A). The individual (Ursa or
contractor) who first discovers the spill is expected to begin notifications and initiate the spill response process
until either the appropriate Ursa employee or contractor representative assumes management of the spill.
A. Discovery
Discovery includes actual or potential spills/releases, and in some cases situations that are not a spill or release,
but a situation where someone has reported an instance as such. In any event, it is important to confirm that
an actual or potential spill situation has occurred before implementing spill response. If in doubt contact the
appropriate spill response personnel as listed in the Spill Notification and Management Protocol (Appendix
A) for assistance prior to implementing this plan.
If a spill or release presents an actual or immediate and sisnifÏcant threat to
human health, safetyo or environment, call 911 or Ursa Health and Safety
representative (APPENDIX A)o secure the location, evacuate personnel and
move away from the release.
B. Containment
Containment, for purposes of this plan, means stopping the spill or release from increasing in volume, size or
duration. The person(s) who discover the spill should attempt to contain the spill only if safe to do so.
Under no circumstances should field personnel attempt to manage a spill or situation without adequate
training, personal protective equipment (PPE) or without exercising extreme caution.
If there is no immediate threat to human health, safety or the environment, and the spill can be safely
contained then personnel can:
Spill containment options and materials used may vary depending upon the media affected. Spill kits should
be in all vehicles or on location; or there should be spill kits immediately available (within l5 - 30 minutes).
Ursa maintains two (2) fully stocked spill response trailers for use in containing larger spills, spills on
transportation arteries, or to aid in preventinþ spills or releases from impacting surface water or surface water
features. The trailer is located at the Rifle office, as well as within Battlement Mesa, and can be towed to a
spill location in relatively short time by Ursa or contractor spill response personnel.
C. Notification (Ursa/Contractors)
The person discovering the spill must make initial notifications in accordance with the Spill Notification
and Management Protocol (Appendix A).
*URGENT NOTIFICATION REQUIREMENT*
For any petroleum product spill/release that reaches live water or has the
potential to reach live water; personnel must notify the appropriate Ursa
Operations Lead !¡qrygþþly, and mitigate the spill from spreading or
affecting downstream waters by setting up a barrier / dam at the closest
downstream control point with access. Vac trucks must be called in
immediately.
Do not attempt to contain the if unsafe to do so.
D. Response
1. Company Spills
Spills in which Ursa is the responsible party, response actions will be determined by one or a combination of
Ursa desigñated personnel identified in the Spill Notification and Management Protocol (Appendix A)'
typically the appropriate operations lead, or their designated representative. After all spill notifications have
been made as outlined in Appendix A, Ursa Spill Management Protocol will be implemented to determine
responsible party, remediation efforts, and closure documentation as outlined in Appendix B.
The Ursa Spill Coordinator will perform the following response actions:
1) Assist the Ursa Regulatory and Operational Leads in identifying further response actions as needed
using approved spill response contractors
2) Investigate using the Environmental Spill/Release Investigation Form (Appendix C)
a. Provide a copy to Ursa Environmental Team within 12 hours
3) Perform required federal and/or state notifications if required (Appendix D)
2. Contractor Spills
Spills in which the cause of the release is due to a contractor operating on an Ursa lease, all financial costs
incurred with spill notification, mitigation, remediation, waste disposal, and required analytical testing is the
responsibility of the contractor at fault.
Contractors may utilize lJrsa's spill contractor (HCSI) to manage the release and ensure proper remediation
in accordance with Ursa policies and procedures, as well as agency regulatory requirements. The contractor
may wish to use their own environmental contractor so long as the following criterion is met;
conducted.
contractor use.
protocols. and submitted to a NELAP Accredited laboratory.
Contractor Spill, response actions will be conducted in accordance with this
Spill Response Plan and the contractoros own Spill Prevention and Response
Plan. This includes response, containment, remediation, and corrective
actions necessary to minimize the potential for future spills.
Ursa reserves the right to initiate spill response actions if there is an immediate
and/or significant threat to the environment, and contactors are unable,
unavailable, or unwilling to do so; until such time as the contractor assumes
manasement of the snill. This in no way relieves contractors of the
requirements and expectations under Section IV of this plan.
Contractors are required to complete the shaded portion of the
Environmental SpilVRelease Investigation Form (Appendix C)
IMMEDIATELY upon the discovery of a spill for verbal notifications as
outlined in Appendix A. A copy must be provide to the Ursa Ops Lead and
Spill Program Lead within 12 hours of discovery of the spilVrelease.
Once remediation has been completed, copies of all records must be provided to Ursa. Copies of required
information include, but is not limited to;
It is important to remember that a contractor spill or release of an Ursa owned material is obligated to remediate
and dispose of the released material in accordance with lJrsa's spill prevention and response and waste
management plans and related policies and procedures.
Waste generated by a spill/release from an Ursa owned material (flowback, produced water, condensate, etc.)
or on an Ursa lease/owned property (well pad, access road, etc.), may not be managed at the contractor's yard
or facility, unless the facility is properly permitted by the COGCC and CDPHE to accept and manage waste.
Once Ursa owned waste from a spill/release is loaded into its packaging container for disposal transporting,
unloading is not allowed anywhere other than the designated disposal facility.
Wastes generated by contractors and is not associated with any Ursa owned material and the release did not
occur on an Ursa location (county road, highway, etc.) is the responsibility of the contractor to provide the
necessary agency reporting and remediation.
E. Agency Notifïcations & Reporting
Federal and state verbal notification and reporting requirements for spills are based on two primary criteria:
1. The type and volume of material spilled; and
2. Affected environmental media (i.e. soil, water)
These materials are further sub-divided into two categories:
1. Exploration and Production Waste (E&P Waste) such as produced water, condensate, or any other
material that has been down hole; and
2. Non-E&P Waste such as fuels and oils. This would include materials such as diesel fuel, hydraulic
oil, motor oil, and glycol.
The most common materials encountered when responding to spills and the associated notification volumes
are outlined in (Appendix D). For materials that are not listed in Appendix D, the MSDS can be used to assist
Contractors are required to include and maintain a current listing of all
chemicals, substances and wastes used in their operations (as well as the
applicable MSDS) in their Spill Prevention and Response Plan.
in determining proper notification should the reportable quantity be exceeded. Contact information for federal
and state agencies is outlined in (Appendix D.1).
Ursa uses the internal notifrcation and management requirements outlined in (Appendix A & B) to track and
document the cause of spills and to assess and manage risk.
Even though a spill may not require verbal notification, it may require
written notification. This includes all spills or releases within secondary
containment structures; steel or earthen, lined or unlined.
F. Remediation
In some instances, remediation (beyond response actions and usually longer term) may be required when
a spill occurs. Spill remediation is dependent on the type of material spilled, the volume spilled, the
location of the spill, spill containment BMPs, pad reclamation status, etc.
In the event a spill is remediated and the accumulation of either E&P or Non-E&P waste, the waste must
be properly stored, treated on-site or transported and disposed of at Federal and state permitted and
approved disposal facility in accordance with lJrsa's Waste Management Plan.
G. Waste Management
Waste generated from spills and releases on Ursa leases must be managed in accordance with the Ursa
Waste Management Plan as well as approved by Ursa management. No waste generated from a
spill/release is allowed to leave the site that it was generated on without prior Ursa approval.
VII.Training
All Ursa and contractor personnel are required to complete SPCC/and spill response training on an annual basis.
At a minimum this includes Operations Managers, Field Supervisors, and EHS management and staff.
Contractors are responsible for training their employees and subcontractors.
It is strongly recommended that Ursa and contractor personnel performing field response and remediation
activities complete fhe24-Hour HAZWOPER course or other applicable training and annual refresher courses..
vrII.
A.
SpilURelease Costs and Invoicing
Ursa Responsible Spills
All Ursa spills must be billed to the appropriate well pad / project regardless of where the spill actually
occurred.
B. Contractor spills
If it is determined that a contractor is responsible of a spill due to negligence, unqualified,
irresponsible, or oversight on their behalf, all costs associated with reporting, remediation, and waste
management of materials associated with the spill will be at the expense of the contractor.
VI[I. Spitt Response and Remediation Tracking
A. Spill response and remediation tracking is cunently implemented and ongoing. Spill tracking is updated
weekly, or as needed, and can be viewed on the Ursa drive located below;
Z:\REGULATORY - ENVIRONMENTAL MGMT\SPILLS-INCIDENTS-INSPECTIONS\02
Compliance\SPlll TRACKING
ffiursa,Kiåiff
Appendix A
Golorado Operations
SPILL NOTIFICATION & MANAGEMENT PROTOCOL
(spt LLS, ENV| RON MENTAL r NCr DENTSÆHREATS)
SPILL DISCOVERY - VERBAL NOTIFICATION
Conta¡n Control Release
(if safe to do so)
lf no supervisor is present,
contact your company
supervisor
Notify on-S¡te Supervisor
IMMEDIATELY
Procedures
MAJOR INCIDENT
W Potential Fines
to Live water
REPORT IMMEDIATELY
TO URSA- DENVER
Spill
Off-Site
Damage
Unless Delegated by Ursa
Lead to another Ursã
representative
(pumper, contractor, etc)
Contact Ursa Operations Lead
Matt Honeycutt - Operations/Construct¡on - 970-812-2198
Hans V!!chgram - Drilling - 303-884-9079
Shane Vaughn - Production - 970-623-9539
Pake Younger - Completions - 970-260-2423
Dave Hayes - Wasatch & Water Lines - 970-250-2590
Environmental
Dwayne Knudson
970-456-3335
Env¡ronmental Back Up's
Rob Ble¡l 720-425-0303
Kr¡s Rowe 970-261-2015
Health and Safety
Tara Mall 970-618-2155
Land & Property
John Doose 970-379-0008
WRITTEN NOTIFICATION
Supervisor to Complete Ursa
lncident lnvest¡gat¡on Form
(Shaded area w¡th¡n fiLbggfs of discovery)
Prov¡de Copy to Kris Rowe w¡lh
HCSt
Veriry Volumes - lnform
Ursa Leads of any
volume changes
Environmental
Dwayne Knudson
970-456-3335
Complete Rema¡n¡ng Sections of
lncident lnvestigation Form
lnclude Spill on Ursa Daily Report
URSA SPILL MANAGEMENT PROTOCOL
(Appendix B)
ffiursa Appendix B
_.r:t,J'i l,'.ll-.
,:r-$,tpt\.'.j!Colorado Operations
Ursa Spill Response Actions and Management Protocol
(BILLING ARRANGEMENTS)
URSA SPILL MANAGEMENT PROTOCOL
Responsible Party Determination Confirm lnitial / Mobilized Spill
clean-Up (billing)
May be necessary to wait for
operations to be completed on-siteRemediation I Clean UpCoccc Form 27 Remediation
(if applicable)
Gonfirmation Sampling
Confirmation Exceeds Agency
Thresholds -Additional
Remediation Required
Obtain disposal documentationWaste Characterizat¡on
(E&P or Non-E&P)Waste Management I Disposal
Follow Waste Plan for Management
Guidance Root Cause Analysis
Conduct contractor meeting with Ursa
Management
(if needed)
Corrective Actions Analysis I Training
A spill stand-down may be issued
by Ursa Management on a case by
case basis
Form27 Notice of Completion Form 19 Supplement - Within 10 Days
BLM NTL-34- Upon Request
Local and State Agency Follow-up
Reporting
No Further Action
Spill Closed I No Further Action (NFA)
ENVI RONM ENTAL SPI LL/RELEASE I NVESTIGATION
Follow Ursa Offical Use)
Waste t (Requires Ursa Approval)
N OTI F IC AT I O N/ REP O RT I NG A CT'ONS be
APPENDIX C
Pad/Location
Report Date:
Responsible Partv
URSA OP's PHASE
CONTRACTOR:
*Attach B¡ll¡ng lnfo
Ursa - K.Rowe
ffiUrsa,[],Tfiâii].i"
ied release)
Occurred:Time:Díscovered By:Company:Ph:
Est. Volume:Mater¡al Released Withín3l7BArea? ( )NO () YES
Sp¡ll ContainedonLocat¡on {)NO (}Yes LiveWaterlmpacted?()NO (}YES WithinSecondaryContainment?{}NO(}YES
stGNtFlcANT THREAT TO HUMANS OR ENVTRONMENT ( ) NO ( ) YES - lmplement Emergency Response Plan
3178 AREATANDS AFFECTED MEDIA AFFECTEDINCIDENT LOCATION RELEASE TYPE
E&P Waste
Non- E&P
Private
Federal
Split Estate
) weil Pad
) Facility
) Transportation (DOT)
Land/Soil
Waters (U.S)
Wetla n d/Riperia n
Ground Water
Buffer Zone
Water lmpacted
N/A
( ) other:On- Lease
off- Lease
( ) other:
INCIDENT DESCRIPTION (How incident occurred, type of effluent, emissions, chemical, etc.):
VOLUME RECOVERED:
ROOT CAUSE:
PLANS TO IMPTEMENT ADDITIONAT TRAINING (DESCRIBE):
DATE TRAINING COMPLETE:
FtNAt DtSPOStTtON OF WASTE (STORAGE, TREATMENT, DISPOSAL)
POSAT LOCATION
UrsaApproval: ( l NO ( )YES DATE:-
ManifestingRequired: ( ) NO ( ) YES
Written Report¡ng RequiredVerbal Notification RequiredAgency/Owner
Yes NoYesNoDateLandowner
No Date Yes No30GCCYes
Yes NoYesNoDateFED-BLM
Yes NoYesNoDate:DPH E
No Date Yes NoLEPCYes
Yes NoYesNoDateNRC
Yes NoYesNoDateFIRE CHIEF
THIS REPORT MUST BE FILED AND SUBMITTED ¡MMEDIATELY
OF THE INCIDENT TO THE URSA SPILL COORDINATOR
COLORADO AND FEDERAL VERBAL NOTIFCATION & WRITTEN REPORTING PROTOCOLAPPENDIX DLEPC / FiÈ ClúcfWriløR.pônhgUpon Reque$None Emrgency E-mil Within 24 houßUÞnRquelN/AN/AN/AUpon RequdUFnRquetUpon Reque$Upon RequdtVe¡belNotifrdíonlmediatelyInmedialelyN/AInnedidely12tuemil12htffiil24 hrMCÆPAWrincnR@ningUpon RequesN/AN/AN/AUpon RequelN/ÀN/AUpon RequdUFnRquesN/AV€rbolNotifimtíonImediablyN/AN/AN/AtrmediatelyN/AN/AUpon RqùelUpon Reqùe$N/AN/ABLMwdffiRcportürtl5 dâysI 5 days15 days15 dâys15 days72 hsN/AI 5 dayst5 days72 tu (mil)15 dâys (ñû--34)72 hf (eMil)l5 days (NIL-34)15 daysVcrbalNotifi@tionfmedialely24 hre24 hß24 hßImedialelyN/AN/A24 hñImmdiarelvN/AN/A24 hßCDPÍIEWrincnRcpoiing5 DaysN/AN/A5 dåys5 Days55 days5 days5 days55 days55 dayss5 days5VeòâlNotifiøtionImmediatelyN/AN/AN/AIrmediâtely24 hoN24 hß24 honßImmediately24 hß24 h624 hßcoGccWritbtrRcpofi¡¡gl0 DaysIniti¡l Repor - 72 hsFom l9 - l0 Dayslnirial Repon - 72 hßFom l9 - l0 Daysldtial R€pot - 72 hñFom 19 - l0 DaysUponReqùelN/AN/AN/ÀN/AN/AN/ANotiñ6üo¡Immedidely24 hð24 hs24 hßInmediatelyN/.\N/AN/AN/AN/AN/AffiimrmRepoÉAnyI bbl or gMter5 bbls. orgstq>l00bblsAny> 25 galloß> 42O Eial(l0bbls.)> 4,200 gal(l00bbÌ)RepofableQüntity (RQ)<RQ büt > l0bbls.<RQ bú >lo0bbls.Md¡r ÂfiæHSùdace mter /GrcüdMterSoil OutsideConbimenlSoil -hsideConbiffientSürfâce mter /GrcúdMterSoilSurface mter /GoudwaterSoiÌClmlslE&PNon E&PEydrecarbon B¡*dNotr E&P OthcrFootnote:1. Notilication ¡nd reporfing requirements that are listed above are for the most common chemicals encountered in day to d¿y Urs¡ operations.2. For chemicals not listed, consult the MSDS for the chemical ofconcern or call an Urs¡ environmcntal tc¡m lcâd.3. Reportable quatrtit¡es that are reported by weight need to be converted to a barrel or gallon equivalent for Fede¡al reporting and notificatiotr requirements.4. Noti& the Ståte Highwåy Patrol for transportåtion related spills involving heårdous m¡teri¿ls.5. Noti& the Bureau ofLand Managemetrt for spills on federal lands as applicable above.
COLORADO AND FEDERAL REPORTING CONTACT INFORMATION Appendix D
AGENCY CONTACT IruMBER E-Mail ADDRESS
Iocal and State Agencies
Parachute Fire Chief David Blair 910-285-9119 (o)
970-250-985 I (c)firechief@gvfpd.org 0124 Stone Quarry Rd.
Parachute. CO 81635
Rifle Fire Chief
Chad Harris 970-625-1243 (o)
970-379-9681 (c)Chad.Haris@crfs.us 1850 Railroad Ave.
Rifle, CO 81650Silt Fire Chief
CDPI{E Bob Peterson
.Tohn O'Rourke
970-248-7151(Bob)
719-269-5327 (Ioln)
I -877-5 I 8-5608 [24-hr]
Robert.Peterson@dphe. state. co.us
or
John. Orourke@,state. co.us
4300 Cherry Creek Drive South
Denver, CO 80246
CDNR Assigned at call I -800-536-5308 Assigned at time of call 1313 Sherman Street, Room 718
Denver, CO 80203
CO Dept. of
Transportation Joel Berschauer 970-640-0348 Joel.Berschauer@dot.state.co.us 222 South 6th St. Room 100
Grand Junction, CO I I 501
COGCC Carlos Lujan (970)-625-2497 or
(303) 894-2100 Carlos.Luj an@state. co.us
I 120 Lincoln Street, Suite 801
Denver, CO 80203
Garfield Counfy
oEM (LEPC)Kirby Wynn (970) e45-04s3 kwynn@garfi eld-county. com
Kirby Wynn
107 8th Street
Rifle, CO 80751
Garfield County
Health Agency Morgan Hill (970) 625-5200 ext 8 1 06
970-379-3826 mhill@garfi eld-couny. com 195 W. l4th Street
Rifle, CO 81650
Pitkin County OEM
Alex Burchetta
or
Cindy Mohat
970-920-5037 alex.burchetta@p itkinsheriff. com
Cindy Mohat
Emergency Management Cord.
Pitkin County sheriff s Ofhce
506 E. Main
Asþen, CO 81611
Silt Public Water
Intake
Jack Castle
Or
Gerry Pace
970-876-2353 ext 817
970-876-5444
970-876-0460
jackc@townoßilt.org
231 N. 7th Street
PO Box 70
silt, co 81652
Rifle Public Water
Intake Dick Deussen 970-66s-6590 ddeussen@rifleco.org 202 W. Railroad Av
Rifle, CO 81650
Parachute Public
Water Intake Mark King 970-285-7630 (office)
970-986-1 82 I (cell)mking@parachutecolorado. com
222Grand Valley Way
PO Box 100
Parachute, CO 81635
Federal Aeencies
National Response
Center Assigned @ Call t-800-424-8802
Available 24 hours
HQS-DG-lst-
NRCINFO@uscg.mil
2703 Marfin Luther King Jr Ave.
SE, STOP 7713
Washinston. DC 20593-77 13
US Dept. of
Transportation Assigned @ Call (202) 366-4000 N/A 1200 New Jersey Avenue, SE
Washington, D.C.20590
Environmental
Protection Agency Assigned @ Call (202) 272-0167 N/A
Ariel Rios Building
1200 Pennsylvania Ave., NW
Washington, DC20460
Bureau ofland
Management Jim Byers 970-876-9056 (o)
970-319-2532 (c)jbyers@blm.gov 2850 Youngheld Street
Lakewood, CO 80215
ffiursa üilrRÄi¡r',Jc",C(}MF'AþJY
U.S. Operations
792 Buckhorn Drive
Denver, CO 80265
(720) 580-8350
Field-wide Spill PreYention,
Control, and
Countermeasure Plan
Colorado Operations
Garfield County, Colorado
July 2013
Rev #: 3 (Marchã0l4)
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Wursa , tPEI?ATll.'¡ü.COMTIAIdY
Colorado Operations
950 7/h sÛeet, suite 2200
Denver, CO 80202-2805
(720) 279-ss0o
Field-wide Spill Prevention,
Control, and
Countermeasure Plan
Colorado Operations
July 2013
Rev #: 3 (March2014)
@r:csJ
Prepared by:
HRL Compliance Solutions, Inc.
2385 F % Road
Grand Junction, CO 81505
THIS PAGE LEFT BLANK FOR TWO.SIDED DUPLICATION
Contents
Regulatory Cross-Reference for an Onshore Production Facility.....
Regulatory Decision Matrix.........
1.0 SPCC PLAN APPROVALS AND CERTIFICATIONS
1.1 Management Approval and Review
1.2 Professional EngineerCertification
1 .3 Substantial Harm Certification Example Form . ... ....... '.
Battlement Mesa Substantial Harm Certifi cations ..................
Castle Springs/Wolf Creek Substantial Harm Certifications ... "...
North Gravel TrendlRoan Substantial Harm Certifi cations........
t
8
9
9
1.3.1
1.3.2
1.3.3
10
L1.
t2
L6
z7
281.3.4 Gravel Trend Substantial Harm Certifications.......
1.4 Plan Review and Amendments............'
2.0 FACILITIES, PROCEDURES, METHODS, OR EQUIPMENT NOT YET FULLY
OPERATIONAL ................
3.0 SPCCPLANPOLICIESANDPROCEDURES
3.1 Owner Information
3.1.1 Facility Layout........
3.1.2 Tanks, PipingandEquipment..............
3.2 General Requirements..........
3.2.1 Discovery, Response and Cleanup of Releases
3.2.2 NotificationContacts
) -z.t Notification Forms........
3.2.4 Response Plan............
3.3 Routine Facility Operations, Inspections and Maintenance.............
3.3.1 FacilityOperations..
..........7L
...........73
74
75
75
.............. 75
3.1.3 Containment Structures...
3.7.3.a Additional Regulatory Requirements : ................
3.1.4 Potential Discharge Volume and Direction of Flow'.'.
3.1.5 Proximity to Navigable Waters...
3.1.6 Site Specific Facility Diagrams....
3.1.7 SPCC Plan Development Tables....'..
76
76
80
...80
80
... 8L
.............. 82
..............e2
..............82
82
82
83
83
833.3.2 Facility Inspection Program ......,......... ........,....
il
3.3.2.a Testing and Record Keeping Guidance
3.3.4 Maintenance Program
3.4 Response and Reporting Information............
3.4.1 SpillResponse................
3.4.2 Spill Reporting
3.5 Spill Response Training
3.5.1 AnnualTraining......
3.5.2 DischargePreventionBriefings
3.5.3 Training Records
APPENDICES
AppendixA Site Specific SPCC Plans
Appendix B Oil Spill Contingency Plan and Emergency Response Plan
Appendix C Discharge Notification Forms
Appendix D SPCC Forms
Appendix E Summary of Operating Procedures and Flowline Maintenance Program
Appendix F Written Commitment of Manpower
ATTACHMENTS
Attachment I Onshore Order 3
85
86
87
87
87
89
89
89
89
il
Ursa Operating Company LLC Oil Production Facility SPCC Plan
Regulatory Cross-Reference for an Onshore Production Facility
t.4$112.3(bX2)
SPCC Plan prepared within six months after becoming
operational (effective | | / l0 12010)
1.4$112.3(dXl)
Professional Engineer (PE) certification with ftve, or six
(if applicable for produced water containers) elements
t.4Amendment of SPCC Plan$112.5(a)
1.4Review of Plan at least every 5 years with documentation
(i.e. alog)$112.5(b)
N/A$112.6 criteriaQualifi ed Facilities : meets
2.0 -3.5strz.7
General requirements for SPCC Plans for all facilities &
all oil types
1.1Management approval of Plançrr2.7
2.0
Discussion of facilities, procedures, methods or
equipment not yet fully operational with details of
installation and operational start-up
çrr2.7
3.0 - 3.5General requirements; discussion of facility's
conformance with rule requirements$112.7(a)(1)
N/ADeviations from Plan requirementsÇ1t2.7(a)(2)
Site Specific Plan
in Appendix A
Facility description and diagram, type of oil and capacity
of each container, transfer stations and piping, buried
containers on diagram
$112.7(a)(3)
3.2 -3.3Discharge prevention measures$112.7(aX3Xii)
3.2 - 3.3Discharge drainage controls$112.7(aX3Xiii)
3.4 and Appendix
B
Countermeasures for discharge discovery, response and
cleanup$112.7(aX3Xiv)
3.4Methods of disposal of recovered materials in accordance
with legal requirements$112.7(aX3Xv)
L
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.4 and3.5
Contact list and phone numbers for facility Incident
Commander, National Response Center, cleanup
contractors, all Federal, State, and local agencies who
must be contacted in case of a discharge
$ 1 12.7(a)(3)(vi)
3.4Spill reporting information5112.7(a)Ø)
Appendix ADischarge procedures$112.7(aX5)
3.I.4 and
Appendix A
Tables and
Diagrams
Failure prediction (sources, quantities, rates, and
directions)$112.7(b)
3.1.3 and
Appendix A
Tables Diagrams
$ I 12.7(c)
Secondary containment for all areas from which a
discharge of oil could occur (i.e. mobile refuelers,
loading/unloading areas, transformers, oil fi lled
operational equipment, etc.)other than bulk containers
N/A$112.7(d)Explanation of impracticability of secondary containment
3.2 -3.3$112.7(a)(3)(ii)Discharge prevention measures
3.2-3.3D ischarge drainage controls$112.7(aX3XiiÐ
3.4 and
Appendix B
Countermeasures for discharge discovery, response and
cleanup$112.7(aX3Xiv)
3.4Methods of disposal of recovered materials in accordance
with legal requirements$112.7(aX3Xv)
3.3 and
Appendix E$112.7(aX3Xii)D ischarge prevention measures
3.3, Appendix A
Tables$112.7(aX3Xiii)Discharge drainage controls
2
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.4 and
Appendix B$ I 12.7(a)(3)(iv)Countermeasures for discharge discovery, response and
cleanup
3.4$112.7(a)(3)(v)
Methods of disposal of recovered materials in accordance
with legal requirements
3.4 and
Appendix B$ l12.7(a)(3)(vi)
Contact list and phone numbers for facility response
coordinator, National Response Center, cleanup
contractors, all Federal, State, and local agencies who
must be contacted in case of a discharge
3.4 and
Appendix B$112.7(a)(a)Spill reporting information
Appendix ADischarge procedures$112.7(a)(s)
3.I.4 and
Appendix A
Tables and
Diagrams
Failure prediction (sources, quantities, rates, and
directions)$112.7(b)
3.1.1, Appendix
A Tables and
Diagrams
$112.7(c)
Secondary containment for all areas from which a
discharge of oil could occur (i.e. mobile refuelers,
loading/unloading areas, transformers, oil fi lled
operational equipment, etc.) other than bulk containers
N/AExplanation of impracticability of secondary containment$112.7(d)
3.1.4 and
Appendix BOil spill contingency plan per part 109$112.7(dX1)
Appendix F$l r2.7(dx2)Commitment of manpower, equipment &, materials to
remove a discharge
aaJ.J$ I 12.7(e)Written procedures for inspections and tests
3.3.2 and
Appendix D$ I 12.7(e)Records of inspections and tests signed and kept 3 years
3.5 and
Appendix D$112.7(Ð(1)Employee training
3.r,3.2.2,3,4ç112.7(Ð(2)
Designated individual accountable for discharge
prevention
3.4 and
Appendix D$112.7(Ð(3)
Discharge prevention briefings scheduled and conducted
annually
N/ALoading/unloading rack (excluding offshore facilities)$r 12.7(h)
Appendix A
Tables$112.7(hxl)Containment for contents of largest compartment
Appendix E$112.7(hX2)
Warning light/sign, barrier system, wheel chocks, or break
interlock system to prevent departure with connected lines
3
Ursa Operating Company LLC Oil Production Facility SPCC Plan
Appendix EInspect drains and outlets of vehicles$112.7(hX3)
NA - no field
constructed
tanks to be
utilized
$112.7(i)
Brittle fracture or catastrophic failure evaluation
requirements
3.0,3.2.1., and
Appendix AConformance with State requirements$112.7(i)
N/AQualified Oil-Filled Operational Equipment: meets
criteria$112.3(kX1)
J.J$112.7(kX2XÐ Inspection procedures or monitoring program
Appendix Bçr12.7(k)(2xiÐ(A)Oil spill contingency plan per part 109
Appendix B
and Appendix Fçtr2.7(k)(2xiixB)Written commitment of resources
NiA$ 112.8
Spill Prevention, Control, and Countermeasure Plan
requirements for onshore facilities (excluding production
facilities)
All$ 112.e
Spill Prevention, Control, and Countermeasure Plan
Requirements for onshore oil production facilities
(excluding drilling and workover facilities).
All$ 112.e(a)Meet general and specific requirements
J.J
Oil production facility drainage: Restrain drainage from
diked areas; remove accumulated oil$ 112.e(bx1)
J,J$ 112.e(bx2)
Oil production facility drainage: Inspect field drainages,
oil traps, sumps or skimmers for accumulations of oil,
remove oil
2.0$ 112.e(c)Oil production facility bulk storage contatners
3.1
Containers compatible with material and conditions of
storage$ 112.e(c)(l)
Appendix A$ 112.e(c)(2)
Secondary containment for tank baffery, separation and
treating units with capacity of largest container &
freeboard for precipitation
N/A
Drainage from undiked areas with potential to discharge
oil directed to catchment basin or holding pond$ 112.e(c)(2)
4
Ursa Operating Company LLC Oil Production Facility SPCC Plan
-t.-tVisually inspect containers, foundations and supports
$ 112.e(cX3)
Appendix AEngineered to prevent discharges
$ 112.e(c)(a)
N/A$ 112.e(c)(s)
Flow-through Process Vessel Alternative in lieu of
compliance with 112.9(c)(2) and (3)
2.0
Produced Water Containers comply with $112.9(c)(1)
and (cX4); and $112.9(c)(2) and (c)(3),$ 112.e(c)(6)
J.JFacility transfer operations, oil production facilities
$ 112.e(d)
aaJ.J$ 1l2.e(dxl)
Inspect aboveground valves, piping, drip pans, supports,
pumping, and etc.
N/A$ 112.e(dx2)Inspect salt water disposal facilities
Appendix A
Flowlines and intra-facility gathering lines are provided
with secondary containment per I12.7(c)$ 112.e(dx3)
Appendix B
For flowlines and intra-facility gathering lines that are
not provided with secondary containment, a Contingency
Plan following the provisions of Part 109 is included$ r 12.e(dx3xÐ
Appendix B
and
Appendix F
$ 112.e(dx3)
For flowlines and intra-facility gathering lines that are
not provided with secondary containment, a written
commitment of manpower, equipment, and materials
required to expeditiously control and remove any
quantity of oil discharged that might be harmful is
provided
Appendix E
A written program of flowline lirúra-facility gathering
line maintenance has been prepared and implemented$ 112.e(dx4)
3.1$ 112.e(dX4XÐ
Flowlines and intra-facility gathering lines and
associated valves and equipment are compatible with the
type of production fluids, their potential corrosivity,
volume, and pressure, and other conditions expected in
the operational environment
5
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.3 and
Appendix E
Procedures to visually inspect and/or test flowlines and
intra-facility gathering lines and associated
appurtenances on a periodic and regular schedule for
leaks, oil discharges, corrosion, or other conditions that
could lead to a discharge are included. For flowlines and
intra-facility gathering lines that are not provided with
secondary containment in accordance with $112.7(c), the
frequency and type of testing must allow for the
implementation of a contingency plan as described under
Part 109
$ 112.e(dx4xiÐ
J.J
Take corrective action or make repairs to any flowlines
and intra-facility gathering lines and associated
appurtenances as indicated by regularly scheduled visual
inspections, tests, or evidence of a discharge.
$ l r2.e(dx4xiiÐ
Procedures to promptly remove or initiate actions to
stabilize and remediate any accumulations of oil
discharges associated with fl owlines, intra-facility
gathering lines, and associated appurtenances
3.3 and
Appendix B$ 1r2.e(dx4xiiÐ
N/A$ 112.10
Spill Prevention, Control, and Countermeasure Plan
requirements for onshore oil drilling and workover
facilities.
1.3
Completed and signed certification of substantial harm
form.$112.20(e)
NA$ r 12.11
Spill Prevention, Control, and Countermeasure Plan
requirements for offshore oil drilling, production, or
workover facilities.
3.1 and
Appendix ACOGCC 3I7B.d
Requirements for DCPS Operations at New Oil and Gas
Locations in the Intermediate Buffer Zone:
6
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.1 and Appendix
A
Building specs for crude oil and condensate tanks, tank
location/distance requirements, berm construction
requirements, tank labeling requirements.
coGCC 604. Oil
and Gas
Facilities
3.1 and Appendix
ACOGCC 605.a.Crude Oil and Condensate Tanks.
3.4 andAppendix CCOGCC 906
Series Rules
Protocol specified for spills and releases in association
with O&G operations.
Appendix A
For all oil and gas operations on Federal and Indian
leases (except Osage), Onshore Order 3 specifies
requirements pertaining to site security.
Onshore Order 3
7
Ursa Operating Company LLC oil Production Facility SPCC Plan
Regulatory Decision Matrix
Federal
Regulation
40 cFR $ l 12, FRP Onshore Order 340 cFR $ l 12, SPCC
CDPHECOGCC Series Rules 7 C.C.R. l10l-14, (non-E&P)State
Regulation
All Locations 604 Series - Setback Locations.
300 Series - 3178 Locations - Regulatory
guidance for 3 178 areas will be updated
due to an invalid reference within the
regulations.
210.b.(2) Tank Battery
Label Requirements
210.d Tank and Container
Label Requirements
210.e General Sign
Requirements
605.a.(1) Tank Standards605.a Crude Oil and
Condensate Tanks
906.e Secondary
Containment Requirements
60s.a.(2),(3),(s),(6),
(7),(8),(l I ) Tank Placement
Distances from other
equipment
COGCC Form 2A COA's
605.a.(4) Berm Construction
Landowner COA's
605.a.(9)Tank Gauges
605.a.(10) Vent Lines
8
Ursa Operating Company LLC Oil Production Facility SPCC Plan
1.0 SPCC PLAN APPROVALS AND CERTIF'ICATIONS
1.1 Management Approval and Review
Ursa Operating Company LLC is committed to the implementation of the procedures outlined
in this SPCC Plan and to the prevention of any release of oil to navigable waters of the United
States of America. A copy of this Plan shall be maintained at the Ursa Operating Company LLC
Rifle, Colorado office and will be made available to the EPA Regional Administrator for on-site
review during normal working hours.
Authorized Management Representative:
Signature:
Name: Robert B
Title: Ursa Resulatory & Environmental Manaser
9
Ursa Operating üompaay LLC Oil Production Facility SPCC Plan
1.2 Professional Engineer Certifiqation
Date of Most Recent Plan Technical ReviewlPE Certification:
February 4,2014.
Ey means of thís certification, I attest that:
* I ain lamiliar with the requkements of the SPCC rule (40 CFR 112);
- The facility has been visíted and examined by myself or my agen!
- This Plaq has been prepared in acçordance with good ongineering practíce, including consideration
of applicable industry standards, and with thorequirements of the SPCC rule;
- Procedurss for required inspeotions and testing have bçen established; and,
- This Plan is adequate for the facility.
ûl,.nl^ 4 tuitqII
i
Signature Engineer Date
State Regis,traticn No.State
No¡e: ?he PE's cerlíficatian does rcoî relieve lhe ownerloperator of fhefacility of the fuly of Íully impleme.ntÌng the
SP CC Pt an ía aecardønc¿ with all applícøble reqaírements.
10
Ursa Operating Company LLC
1.4 Plan Review and Amendments
Oil Production Facility SPCC Plan
LOG OF PLAN REVIE\ü AND AMENDMENTS
NON TECHNICAL AMENDMENTS. Non-technical amendments are not certified by a Professional Engineer.
. Examples of changes include, but are not limited to phone numbers, name changes, or any non-
technical text change(s)
TECHNICAL AMENDMENTS. Technical amendments are cerlified by a Professional Engineer.
. Examples of changes include, but are not limited to, commissioning or decommissioning
containers; replacement, reconstruction, or movement of containers; reconstruction, replacement,
or installation of piping systems; construction or demolition that might alter secondary
containment structures; changes of product or service; or addition/deletion of standard operation
or maintenance procedures related to discharge prevention measures. It is the responsibility of the
facility to determine, and confirm with the regulatory authority as necessary, what constitutes a
technical amendment. The preamble of the rule states that an amendment is required only "when
there is a change that materially affects the facility's potential to discharge oil" (67 FR
4709r).. An amendment made under this section will be prepared within six (6) months of the change and
implemented as soon as possible but not later than six (6) months following preparation of the
amendment.
. Technical Amendments affecting various pages within the plan can be P.E. certified on those
pages, certifying those amendments only,and will be documented on the log form below
MANAGEMENT REVIEW
1. Management will review and amend this SPCC Plan at least each five (5) years or when there is a
change in the facility design, construction, operation, or maintenance that materially affects its
potential for a discharge. The review will be documented on the form below.
2. Management will review and amend this SPCC whenever there is a discharge of more than 1000
gallons of oil into or upon navigable waters in a single discharge or a discharge of more than 42
gallons of oil in each of two discharges occurring within any twelve month period. The Plan will
be submitted to the Regional Administrator within 60 days.
REVIEW AND AMENDMENT LOG
Review/
Amend Date Signature *
(Specify)
Amend
Plan
(witt/will
not)
Description of
Review Amendment
Affected
Pages or
Section
PE
Certification
(Y/N)
October 2013 will
Addition of Site Specific
SPCC Plans (Dever C and
Norcross A, both within the
Gravel Trend Field)
Appendix A Yes
December 2013 'will
Addition of Site Specific
SPCC Plan, Castle Springs
Compressor Station
Appendix A Yes
7l
W AND AMENDMENT LOG Continued
Appendix A,
Certification of
Harm pages,
Updated
notification
numbers, reporting
table, inspection
form,3.1.3.a.,
Yeswill
Addition of Site
Specific SPCC Plans,
Speakman A, Mclin
B, Mclin C, non-
technical amendments
February 2014
Yes
Addition of a Site
Specific Plan -
Monument Ridge,
updates to Frei A
storage volume
Appendix A,
Certification of
Harm Pages.
willMarch2014
Ursa Operating Company LLC
*Typically signed by Manager, Professional Engineer or plan reviewer
Oil Production Facility SPCC Plan
72
Ursa Operating Company LLC Oil Production Facility SPCC Plan
2.0 FACILITIES, PROCEDURES, METHODS, OR EQUIPMENT
NOT YET FULLY OPERATIONAL
This SPCC Plan is being drafted in accordance with federal, state and local regulatory
requirements.
Per site inspections completed by a third party consulting group, deficiency items must be
addressed to obtain compliance with federal, state and local SPCC regulations and requirements.
Ursa is aware of the non-compliance items and is making the necessary efforts to address the
compliance items defined in Table 5 of the Site Specific SPCC Plans (Appendix A).
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Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.0 SPCC PLAN POLICIES AND PROCEDURES
This SPCC Plan, hereinafter referred to as 'the plan', is a carefully conceived document prepared
to address onshore production facilities in Colorado operated by Ursa Operating Company LLC
(Ursa) which are subject to the federal SPCC regulations. There are several additional State of
Colorado SPCC-related requirements which are supplemental to the EPA oil pollution
prevention regulations (40 CFR 112). The applicability of these regulations will be discussed in
the site specific spcc plans contained in Appendix A. This plan was developed to satisfy the
applicable state and federal requirements. Specifically, this plan was developed to:
. Communicate pollution prevention requirements to Ursa employees.
. Document Ursa's SPCC procedures and measures.
. Enable Ursa employees to report a spill and provide all the necessary information in the
event of a release.. Assist Ursa in contacting and reporting pertinent information to the appropriate agencies.
. Provide site-specific information in a simple way.
Based on the type of respective operating facilities, the plan addresses both the general plan
regulatory requirements specified in 40 CFR 112.7 and those specific to onshore production
facilities 40 CFR 112.9. To ensure coverage of applicable regulations, a Regulatory Cross
Reference was provided at the beginning of this plan. It identifies salient sections of the
regulation in accordance with the plan section in which it is addressed. General requirements
applicable to each facility and to the overall management of SPCC-related activities are included
in the main text portion of the plan. Appendix A provides site specific information for each
individual facility covered by the SPCC plan. This information includes a site layout, description
of equipment, volume and type of material stored, surface water flow directions, and spill
prevention controls.
Technical amendments, such as addition of hydrocarbon storage containers, to this plan will be
issued within 6 months as mandated by 40 CFR 112.5. Such amendments will be certified by a
professional engineer if the amendment is considered to be technical. In accordance with
pertinent regulations, non-technical Plan amendments/reviews and revisions will also be issued
on a timely basis by personnel with the appropriate level of authority.
This plan conforms to the SPCC Regulations and was developed in accordance with sound
engineering practices. Any deviations from regulatory requirements that were noted during the
development of this plan are noted on Table 2. A complete copy of the SPCC Plan is maintained
at the Rifle Field Office and at the Denver Corporate Office.
74
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.1 Owner Information
Name Ursa Operating Company LLC
Address U.S. Operations
Tg2Buckhorn Drive
Denver, CO 80265
Regional Address:
792Bucl<horn Drive
Rifle CO, 81650
Company Contacts: Robert Bleil, Ursa Regulatory & Environmental Manager
Tara Mall, HSE
Facility Location: This SPCC Plan is applicable to onshore production facilities
operated by Ursa in Colorado. Site specific information is
located within the Appendix A of this plan.
3.1.1 Facility Layout
Details for each facility covered by this plan are provided in Appendix A of this plan. In
general, the physical layout of an onshore production facility is associated most often with a well
pad. Equipment associated with the well pad includes, but is not limited to, separators,
dehydrators, wellheads, above/below ground piping, produced water tanks, condensate tanks,
methanol tanks, production pits, and miscellaneous storage. The equipment on the well pad is
typically organized in a manner which facilitates safe and efficient automobile navigation.
The valves associated with tanks, holding either oil or other chemicals, are kept in the closed and
locked position to help ensure unintentional flow does not occur when the tank is not being
actively used. The area around the tanks is kept free and clear of debris that could pose a safety
hazard (e.g. fire, traffic).
Storm water which flows across uncontained portions of the site is not anticipated to come into
contact with hydrocarbons. Visual inspections of the entire location are performed by designated
personnel or third party contractors as described in Section 3.3 of this plan with regards to SPCC
requirements and the Storm Water Management Plan with regards to storm water management.
3.1.2 Tanks, Piping and Equipment
The condensate and produced water tanks (tanks) are considered bulk storage tanks/containers
under the SPCC regulation. All tanks were built in accordance with API Specification 12F Shop
Welded Tanks for Storage of Production Liquids design. All enclosed tanks are equipped with
gas vents to relieve any pressure that might build up inside the tank, and are also equipped with
vacuum protection that prevent over or under pressuring of the tanks. All tanks are equipped with
hatchways for venting, gauging and/or access. All tanks should have stairways and hand railings
to facilitate worker safety when the gauging operations are underway. The tanks have been
sized to provide sufficient capacity to prevent overflrlling. Tanks are gauged periodically to
75
Ursa Operating Company LLC Oil Production Facility SPCC Plan
monitor the oil level to ensure that sufficient tank capacity is available for storage of produced
water or condensate. It should be noted that separator units are also considered to be bulk storage
containers and are subject to sized secondary containment and periodic inspection. As described
in Section 3.3, tanks are visually inspected on a regular basis for leaks, corrosion, and any
other malfunctions or deterioration. The tanks are also integrity tested prior to placement at the
facility. The equipment and associated hose is compatible with the fluids stored and storage
conditions such as pressure and temperature. Any flowlines are to be compatible with the
materials being transferred through them. Flowlines shall be powder coated andlor painted.
3.1.3 Containment Structures
Corrugated steel containment structures or earthen berms are present to provide secondary
containment for bulk storage structures. The storage volume of the respective secondary
containment is large enough to contain the entire capacity of the largest single container in the
secondary containment plus sufficient freeboard to allow for precipitation taking into account for
displacement as applicable. Additional storage volume may be required in the event the facility is
located in a Colorado Oil and Gas Conservation Commission (COGCC) high density area or the
intermediate or internal3lTB buffer zone.Locations located within setback areas are also subject
to additional containment requirements. Section3.l.3.aprovides the respective information.
In addition, many of the facilities have a perimeter earthen berm around the well pad which can
provide secondary containment for separators, and condensate and produced water loading and
unloading activities. Should a release occur, the earthen berm will prevent migration of the
spilled material away from the site and allow Ursa to control and mitigate the release in a
timely and efficient manner. If a site perimeter berm is utilized as secondary containment, a
waterbar should be installed at the pad's entrance, and any storm water diversion features should
drain to a catchment basin. These structures help to ensure releases of produced water (i.e. oil) at
facility on the surface are contained.
In some areas, there may be additional secondary containment requirements. Please see below for
additional requirements which may be applicable to facilities subject to this spcc plan.
3.L3.a AdditionalRegulatoryRequirements:
COGCC:
For facilities located in a Colorado Oil and Gas Conservation Commission (COGCC) high
density area, andlor a3l7B Area, additional stipulations pertaining to SPCC requirements
will apply as provided below:
COGCC 3I7B.d
Requirements for Drilling Completions Production and Storage Operations at New
Oil and Gas Locations in the Intermediate Buffer Zone: The following shall be
required for all DCPS Operations at New Oil and Gas Locations within a Surface
Water Supply Area and in the Intermediate Buffer Zone as defined in Table l. (l)
Pitless drilling systems; (2) Flowback and stimulation fluids contained within tanks
that are placed on a well pad or in an area with down gradient perimeter berming;
(3) Berms or other containment devices shall be constructed in compliance with
76
Ursa Operating Company LLC Oil Production Facility SPCC Plan
Rule 603=edJ3) 605.a.(4)1 and 906.e.(1)1 around crude oil, condensate, and
produced water storage tanks
COGCC 604. Setback and Mitigation Measures for Oil and Gas Facilities, Drilling, and
Well Serviceing Operations
Exception Zone Setback. No Well or Production Facility shall be located five
hundred (500) feet or less from a Building Unit except as provided in Rules
60a.a.(1) A and B, and 604.b'
Buffer Zone Setback. No Well or Production Facility shall be located one thousand
(1,000) feet or less from a Building Unit until the Operator certifies it has complied
with Rule 306.e. and the Form 2A or Form 2 contains conditions of approval related
to site specific mitigation measures as necessary to eliminate, minimize or mitigate
potential adverse impacts to public health, safety, welfare, the environment, and
wildlife.
High Occupancy Buitdings. No Well or Production Facility shall be located one
thousand (1,000) feet or less from a High Occupancy Building Unit without
Commission approval following Application and Hearing. Exception Zone Setback
mitigation measures pursuant to Rule 604.c. shall be required for Oil and Gas
Locations within one thousand (1,000) feet of a High Occupancy Building, unless
the Commission determines otherwise.
Designated Outside Activity Areas. No Well or Production Facility shall be
located three hundred fifty (350) feet or less from the boundary of a Designated
Outside Activity. The Commission, in its discretion, may establish a setback of
greater than three hundred fifty (350) feet based on the totality of circumstances.
Buffer Zone Setback mitigation measures pursuant to Rule 604.c. shall be required
for Oil and Gas Locations within one thousand (1,000) feet of a Designated Outside
Activity Area, unless the Commission determines otherwise.
Maximum Achievable Setback. If the applicable setback would extend beyond the
area on which the Operator has a legal right to locate the Well or Production
Facilities, the Operator may seek a variance under Rule 502.b. to reduce the setback
to the maximum achievable distance.
Mitigation Measures. The following requirements apply to an Oil and Gas
Location within a Designated Setback Location and such requirements shall be
incorporated into the Form 2A or associated Form2 as Conditions of Approval.
Leak Detection Plan. The Operator shall develop a plan to monitor Production
Facilities on a regular schedule to identify fluid leaks.
Berm construction. Berms or other secondary containment devices in Designated
Setback Locations shall be constructed around crude oil, condensate, and produced
water storage tanks and shall enclose an area sufficient to contain and provide
secondary containment for one-hundred fifty percent (I50%) of the largest single
tank. Berms or other secondary containment devices shall be suffrciently impervious
I The regulatory references are not currently finalized. Upon finalization, the text will be updated.
77
Ursa Operating Company LLC Oil Production Facility SPCC Plan
to contain any spilled or released material. All berms and containment devices shall
be inspected at regular intervals and maintained in good condition. No potential
ignition sources shall be installed inside the secondary containment area unless the
containment area encloses a fired vessel. Refer to American Petroleum Institute
Recommended Practices, API RP - D16.
Tank specifications. All newly installed or replaced crude oil and condensate
storage tanks shall be designed, constructed, and maintained in accordance with
National Fire Protection Association (NFPA) Code 30 (2008 version). The operator
shall maintain written records verifying ptroper design, construction, and
maintenance, and shall make these records available for inspection by the Director.
Only the 2008 version of NFPA Code 30 applies to this rule. This rule does not
include later amendments to, or editions of, the NFPA Code 30. NFPA Code 30 may
be examined at any state publication depository library. Upon request, the Public
Room Administrator at the offîce of the Commission, ll20 Lincoln Street, Suite
801, Denver, Colorado 80203, will provide information about the publisher and the
citation to the material.
Exception Zone Setback. Within the Exception Zone Setback, the following
mitigation measures will be mandatory: . All mitigation measures required pursuant
to subsection 604.c.(2), above, and Berm Construction: i. Containment berms shall
be constructed of steel rings, designed and installed to prevent leakage and resist
degradation from erosion or routine operation. ii. Secondary containment areas for
tanks shall be constructed with a synthetic or engineered liner that contains all
primary containment vessels and flowlines and is mechanically connected to the
steel ring to prevent leakage. iii. For locations within five hundred (500) feet and
upgradient of a surface water body, tertiary containment, such as an earthen berm, is
required around Production Facilities. iv. In an Urban Mitigation Area Exception
Zone Setback, no more than two (2) crude oil or condensate storage tanks shall be
located within a single berm.
COGCC 605. Oil and Gas Facilities
Atmospheric tanks used for crude oil storage shall be built in accordance with the
standards specified with the respective regulation. (2) Tanks shall be located at least
two (2) diameters or three hundred fifty (350) feet, whichever is smaller, from the
boundary of the property on which it is built. Where the property line is a public
way the tanks shall be two thirds (213) of the diameter from the nearest side of the
public way or easement. A. Tanks less than three thousand (3,000) barrels capacity
shall be located at least three (3) feet apart. B. Tanks three thousand (3,000) or more
barrels capacity shall be located at least one-sixth (1/6) the sum of the diameters
apart. When the diameter of one tank is less than one-half (ll2) the diameter of the
adjacent tank, tanks shall be located at least one-half (ll2) the diameter of the
smaller tank apart. (3) At the time of installation, tanks shall be a minimum of two
hundred (200) feet from any building unit.(4) Berms or other secondary containment
devices shall be constructed around crude oil, condensate, and produced water tanks
to provide secondary containment for the largest single tank and sufficient freeboard
to contain precipitation. Berms and secondary containment devices and all
containment areas shall be sufficiently impervious to contain any spilled or released
78
Ursa Operating Company LLC Oil Production Facility SPCC Plan
material. Berms and secondary containment devices shall be inspected at regular
intervals and maintained in good condition. No potential ignition sources shall be
installed inside the secondary containment area unless the containment area encloses
a fired vessel.(5) Tanks shall be a minimum of seventy-five (75) feet from a fired
vessel or heater treater.(6) Tanks shall be a minimum of fifty (50) feet from a
separator, well test unit, or other non-fired equipment.(7) Tanks shall be a minimum
of seventy-fîve (75) feet from a compressor with a rating of 200 horsepower, or
more.(8) Tanks shall be a minimum of seventy-five (75) feet from a wellhead.(9)
Gauge hatches on atmospheric tanks used for crude oil storage shall be closed at all
times when not in use.(10) Vent lines from individual tanks shall be joined and
ultimate discharge shall be directed away from the loading racks and fired vessels in
accord with API RP 12R-1,5th Edition (August l99T,reafftrmed April 2,2008).
Only the 5th Edition of the API standard applies to this rule; later amendments do
not apply. The API standard is available for public inspection during normal
business hours from the Public Room Administrator at the office of the
Commission,lI20 Lincoln Street, Suite 801, Denver, Colorado 80203. In addition,
these materials may be examined at any state publication depository library. (11)
During hot oil treatments on tanks containing thirty-five (35) degree or higher API
gravity oil, hot oil units shall be located a minimum of one hundred (100) feet from
any tank being serviced.
906.e.(1) Spill/Release Prevention Secondary containment.
Secondary containment that was constructed before May I ,2009 on federal land, or
before April l, 2009 on other land, shall comply with the rules in effect at the time
of construction. Secondary containment constructed on or after May I,2009 on
federal land, or on or after April l, 2009 on other land shall be constructed or
installed around all tanks containing oil, condensate, or produced water with greater
than 3,500 milligrams per liter (mg/l) total dissolved solids (TDS) and shall be
sufflrcient to contain the contents of the largest single tank and sufficient freeboard
to contain precipitation. Secondary containment structures shall be sufficiently
impervious to contain discharged material. Operators are also subject to tank and
containment requirements under Rules 603. and 604. This requirement shall not
apply to water tanks with a capacity of fifty (50) barrels or less.
Federal Leases
Onshore Order 3
For facilities which are subject to Onshore Order 3 (i.e. assets located on Federal
leases, or wells and facilities on State or privately-owned mineral lands committed to
a unit or communitization agreement that affects Federal or Indian interests), valves
and other points which oil could be loaded out of will be subject required to be
marked with a unique identifîer called a seal to ensure oil (i.e. condensate) is not
unloaded from the equipment without the volume being documented and provided to
the respective federal agent (i.e. bureau of Land Management official, or Bureau of
Indian Affairs official). For additional information pertaining to the requirements of
79
Ursa Operating Company LLC Oil Production Facility SPCC Plan
this regulation please see Attachment I
3.1 .4 Potential Discharge Volume and Direction of Flow
The direction of flow will be specific to the respective location the facility is associated with, and
is noted within the site specific plan(s) included within Appendix A. Please see below for
examples of potential discharge volumes and causes.
One scenario for release of oil is the loss of containment of the largest tank at any particular
facility due to rupture (300 bbl. example tank size). This could result in the release of up to
12,600 gallons of oil within one hour. Oil would spill into the secondary containment. In this
scenario, oil would be contained within the secondary containment'
Another possible scenario would be the release of oil outside the secondary containment during
truck loading/unloading activities; such as a ruptured hose connection on water truck. This could
result in the release of approximately 150 gallons of oil per minute, until the attendant could
access the shutoff valve. The volume of oil released during this scenario is variable.
A third possible scenario would be the rupture of a flowline outside of secondary containment
due to equipment failure. This could result in the release of approximately 150 gallons of oil per
hour, until the failure is noticed during routine inspections. The volume of oil released during
this scenario is variable.
In all instances, the spill response and notification procedures provided in Ursa's Spill Prevention
and Management Plan would be implemented in an orderly and efficient manner. In addition to
the Spill Prevention and Management Plan, an Oil Spill Contingency Plan is included with this
plan.
3.1.5 Proximity to Navigable Waters
All facilities are located within the Colorado River watershed. The surface water proximity is
illustrated within maps and tables contained in Appendix A. In the event of an uncontrolled
discharge from a facility, oil would follow the natural topography of the landscape. Additionally,
each facility diagram within the site specifîc plan depicts the anticipated direction of runoff from
the facility and the distance relative to the potentially impacted navigable waterway.
3.I.6 Site Specific Facility Diagrams
Site specific facility maps and diagrams are included in Appendix A with the following detail
and location information as applicable:
. Process equipment,. Fixed aboveground storage tanks.. Direction of surface water runoff.. Completely buried and bunkered tanks (including USTs covered under 40 CFR 280 or
281).. Drum and portable container storage areas.. The type of oil and storage capacity.. Material of construction for all containers.
80
Ursa Operating Company LLC
Connecting pipes including intra-facility gathering lines
Oil Production Facility SPCC Plan
a
3.1.7 SPCC Plan Development Tables
Site specifîc SPCC detail tables were drafted for each facility included in this plan. Details from
the development tables such as the number of tanks, capacity, contents, and secondary
containment descriptions are provided in Table s 2, 3 and 4 of the respective site specific plans.
The development tables were creàted to standardize SPCC site inspections and maintain a
database of information including but not limited to:
. General facility information.. Tank information.. Processingequipment.. Containment/loadout information.. Failure information outside of containment.
. Facility property information.
. Surroundingdrainage.. Comments.
81
Ursa Operating Company LLC
3.2 GeneralRequirements
Oil Production Facility SPCC Plan
3.2.1 Discovery, Response and Cleanup of Releases
The respective facilities are inspected routinely as described in Section 3.3.2. In the event a
release is discovered, the protocol provided in the Spill Prevention and Management Plan will be
implemented. Section 3.5.1 of this plan provides guidance with regards to annual training
requirements. It is recommended that oil handling personnel obtain and maintain the appropriate
Hazwoper training for their position. All recovered materials will be handled in accordance with
all applicable federal, state and local laws and regulations as described in the Spill Prevention
and Management Plan and Section 3.4 of this plan.
3.2.2 Notification Contacts
Robert Bleil or Tara Mall:
- 970-625-9922 - Rifle Office Number
- 720-425-0303 - Robert Mobile
- 970-618-2155 -TaruMobile- 720-508-8350 - Denver Office
Please see the flowcharts included in Appendix B if the above personnel cannot be contacted,
should a release occur, additional information is provided in the Spill Prevention and
Management Plan. Prior to any notification to agencies, the Spill Prevention and Management
Plan will be utilized to determine the agency notification requirements.
3.2.3 Notification Forms
The appropriate forms which must be completed prior to reporting a spill are included in this plan
as Appendix D. For additional information, please refer to the Spill Prevention and Response
Plan and Appendix B of this plan.
3.2.4 Response Plan
General information on the response to, and reporting of, oil discharges can be found in the
Spill Prevention and Response Plan. Additional information is located within Section
3.4 of this planandtheattached Oil Spill Contingency Plan, acopy of which is provided in
Appendix B. The Oil Spill Contingency Plan describes procedures that will be implemented
under various emergency scenarios, including when an oil discharge occurs. The plan is also
designed to address releases from areas such as flowlines where secondary containment is not
practical.
82
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.3 Routine Facility Operations, Inspections and Maintenance
Ursa's oil spill prevention program is described in this section of the SPCC plan and includes
routine facility operations, periodic inspections and maintenance activities. It addresses all
routine activities associated with the oil production facilities as required by 40 CFR 1I2.7 and
t12.9.
3.3.1 Facility Operations
All equipment is operated and positioned in a way which is designed to prevent and
contain releases. Load line and drain valves are maintained in a closed position when not in use.
The facility is visited periodically by Ursa personnel. The volume of liquid is gauged and the
fluid level in each tank is urr"Ár"ã prior ìo loading or offloading oil2 when the inventory
approaches the tank capacity. The designated personnel also performs a visual inspection of all
above ground vessels, tank hatches, valves, and secondary containment features to ensure issues
are promptly identified as described in Section 3.3.2.
Tank truck loading/unloading occurs at all the facilities covered in this plan. However, the
facilities will not have a loading/unloading rack as defined by 40 CFR I 12.2. The tanks may be
connected to each other via piping, or each tank may be self-contained within the secondary
containment area. Trucks used to offload oil are positioned adjacent to the secondary containment
structures and are attended by the personnel during all loading and unloading activities. All
loading and unloading activities are conducted by qualified contract personnel who are
trained in proper loading and spill prevention techniques and procedures. Pumper truck
personnel inspect tank truck and transfer lines including drains and outlets on the tank trucks
prior to flrlling and before departure to ensure that there are no leaks or discharges. If necessary,
truck personnel tighten, adjust, or replace equipment that is leaking. Premature vehicular
departures are prevented with.a manual air brake system and oversight. A Summary of Operating
Procedures (SOP) can be found in Appendix E.
3.3.2 Facility Inspection Program
Tanks containing oil are inspected periodically. Designated personnel are trained to identify and
report any leaks or other deficiencies (e.g. compromised secondary containment). Inspections are
conducted on a monthly basis and include review of equipment, tanks, valves, hatches, and
lines; the site drainage system; and the entire tank battery, including the area within the
containment structures and earthen berms. Specifically, each storage vessel, separator, and
miscellaneous equþment is visually inspected for deterioration and maintenance needs, including
the foundation and support of each tank/container located on or above the ground surface. The
inspection also includes visual check of facility transfer equipment including transfer piping and
valves, drip pans, pumping well polish rod stuffing boxes, tanks, separators, heater-treaters, valve
glands and bodies, pipe supports, and bleeder and gauge valves. Inspection of conditions
associated with buried flowlines is accomplished by observing the ground surface above the ,
lines for evidence of leaks on a routine basis. Please see the inspection form included as
Appendix D. It should be noted that some locations will have additional inspection requirements
t Oil ^"uns oil of any kind or in any form, including, but not limited to: fats, oils, or greases of animal, fish, or marine
mammal origin; vegetable oils, including oils from seeds, nuts, fruits, or kemels; and, other oils and greases, including
petroleum, fuel oil, sludge, synthetic oils, mineral oils, oil refuse, or oil mixed with wastes other than dredged spoil.
83
Ursa Operating Company LLC Oil Production Facility SPCC Plan
in accordance with the respective location's COGCC Form 2A conditions of approval. The
approved Form 2A has been included for reference within the respective site specific plans for
locations it was available for. In the event additional Form 2A documents are approved, the
document shall be included within the site specific plans as soon as practical.
During the field inspection, the site drainage systems such as drainage ditches, road ditches, and
intermittent creeks in the vicinity of the facility are inspected for accumulations of oil. Rainwater
and other precipitation that accumulates within the berm is either allowed to evaporate, infiltrate
into underlying soil, or is removed using a vacuum truck. Excess rainwater removed by the
vacuum truck is either returned to storage or transported for offsite disposal at a permitted non-
hazardous disposal facility. No drains are present in the secondary containment structures or
earthen berms. A discharge of rainwater from the secondary containment structures cannot occur
unless the structure fails or is breached.
Observations made by the SPCC inspector are recorded on SPCC/Containment inspection, which
are stored at the Rifle Field Office and the corporate office in Denver. A copy of the
SPCC/Containment inspection form is provided in Appendix D. Mechanical integrity and spill-
related issues are addressed as they are identified.
During the inspection, the site drainage systems such as drainage ditches, road ditches, and
intermittent creeks in the vicinity of the facility are inspected for accumulations of oil. Rainwater
and other precipitation that accumulates within the berm is either allowed to evaporate, infiltrate
into underlying soil, or is removed using a vacuum truck. Excess rainwater removed by the
vacuum truck is either returned to storage for use in storage or transported for offsite disposal at a
permitted non-hazardous disposal facility. No drains are present in the secondary containment
structures or earthen berms. A discharge of rainwater from the secondary containment structures
cannot occur unless the structure fails or is breached.
Oil accumulating within the secondary containment area is removed using absorbent pads or is
removed with excess rainwater using a vacuum truck as described above. Accumulated oil is not
discharged outside of the secondary containment area. Evidence of hydrocarbon spills are noted
and rernediated as appropriate as described in Section 2.4.
Please see below for a table which provides guidance with regards to inspection and testing
recommendations:
84
Ursa Operating Company LLC
3.3.2.a Testing and Record Keeping Guidance
Oil Production Facility SPCC Plan
t12.7(d)Test
Integrity testing. Periodically.
However, because there is no
secondary containment, good
engineering practice may
suggest more frequent testing
than would otherwise be
scheduled.
Bulk storage with no secondary
containment and for which an
impracticability determination has been
made
Test
Integrity and leak testing of
valves and piping associated
with containers that have no
secondary containment as
described in $1 12.7(c).
Periodically.
r12.t(d)
Valves and piping associated with bulk
storage containers with no secondary
containment and for which an
impracticability determination has been
made
1r2.7(e)Record
Keep written procedures and a
signed record ofinspections and
tests for a period ofthree years.
Records kept under usual and
customary business practices
will suffice, for all actions.
Recordkeeping requirement
1r2.7(h)(3)Inspect
Visually inspect. Prior to filling
and departure oftank car or tank
truck.
Lowermost drain and all outlets of tank
car or tank truck
Evaluate potential for brittle
fracture or other catastrophic
failure. When the container
undergoes a repair, alteration,
reconstruction or a change in
service that might affect the risk
of a discharge or failure due to
brittle fracture or other
catastrophe, or has discharged
oil or failed due to brittle
fracture failure or other
catastrophe. Based on the results
of this evaluation, take
accumulated oil on the rainwater
and return it to storage or
dispose of it in accordance with
leeallv approved methods.
to
content. Prior
ou must remove
action
112.e(bx1)
rt2.7(i)Evaluate
Fffiffi-ffi.ffi
Inspect
Field-constructed aboveground
container
Diked area
85
Ursa Operating Company LLC Oil Production Facility SPCC Plan
3.3.4 Maintenance Program
Ursa has a robust maintenance program aimed at eliminating releases of oil and minimizing
unplanned downtime. Preventative maintenance on mechanical equipment (e.g. pumps) is
completed in accordance with manufacturer recommendations to ensure proper operation. Any
equipment requiring maintenance that is identifîed by visual inspections of the facilities are
addressed by either Ursa mechanical staff or third party contractors. Equipment repairs are made
in accordance with the relevant codes and industry standards'
Detect accumulation of oil that
may have resulted from any
small discharge. Inspect at
regularly scheduled intervals.
You must promptly remove any
accumulations of oil.
r12.e(b)(2)InspectField drainage systems, oil traps,
sumps, and skimmers
Inspect
Visually inspect to assess
deterioration and maintenance
needs. Periodically and on a
regular schedule
112.e(cX3)Aboveground containers
r12.e(c)(3)Inspect
Visually inspect to assess
deterioration and maintenance
needs. Periodically and on a
regular schedule
Foundations or supports ofeach
container that is on or above the surface
ofthe ground
112.e(dx1)Inspect
During the inspection, assess
general condition of flange
joints, valve glands and bodies,
drip pans, pipe supports,
pumping well polish rod
stuffing boxes, bleeder and
gauge valves, and other such
items. Periodically and on a
regular schedule.
All aboveground valves and piping
associated with transfer operations
Inspect
Inspect to detect possible system
upsets capable of causing a
discharge. Often, particularly
following a sudden change in
atmospheric temþerature.
r12.e(d)(2)Saltwater disposal facilities
Inspect
Have a program of flowline
maintenance to prevent
discharges from each flowline.
Each program may have its own
specific and individual
inspection, testing, and/ or
evaluation requirements and
frequencies as determined by
the PE.
112.e(dx3)Flowlines
86
Ursa Operating Company LLC
3.4 Response and Reporting Information
Oil Production Facility SPCC Plan
Detailed spill reporting and response procedures are provided in the Spill Prevention and
Response Plan in addition to the information contained within this section. The specific response
protocol utilized will depend on the size and nature of the release.
3.4.1 Spill Response
The Incident Commander (IC) (Rob Bleil) andlor Alternate Incident Commander (AIC) (Tara
Mall) are responsible for implementing response procedures in the event of an oil spill or
discharge emergency. These personnel have the authority to commit the resources necessary to
ca6y out a response. However, all oil handling personnel of Ursa receive training to familiarize
themselves with all aspects of the SPCC Plan, facility operations, the location and characteristics
of materials handled at the facility, the locations of all records within the facility; and are
responsible for proper implementation of response procedures should the IC or AIC be
unavailable.
1. Assess the basic situation;
2. If the incident poses an immediate threat of fire, explosion, or other impact to safety, health,
or the environment, the local fire department will be contacted at 91 1 or relay information
to dispatch via radio;
3. Call the company personnel;
4. If it is safe to enter the area and the personnel are properly trained and certifTed, they can
protect themselves with personal protective equipment (PPE);
5. Eliminate ignition sources;
6. Restrict access;
7. Stop the source ofthe release ifsafe to do so;
8. Contain the spill if possible to safely to so with available spill response inventory items;
9. Report the release to the appropriate authorities listed in Section 8.0;
10.If the spill involves a minor amount of oil, it will be cleaned up by Bargath personnel
provided that:
a. They have current and appropriateHAZWOPER and applicable OSHA training;
b. Appropriate Material Safety Data Sheets (MSDS sheets) are available for the
material spilled; and
c. Appropriate PPE is available and used.
In general, recovered fluids are either returned to an uncompromised tank for storage, or
transported offsite for disposal at a permitted commercial disposal facility. Hydrocarbon
impacted soil is segregated onsite and is tested to assess the contamination of concern identified
in the COGCC Table 910-1. Please see the flowcharts in Appendix B for streamlined spill
response protocol.
3.4.2 Spill Reporting
As described in the Spill Prevention and Response Plan, Emergency Response Plan and the Oil
Spill Contingency Plan, the Incident Commander will be notified in the event of a release.
Notification forms are provided in Appendix C. The forms will document the event concisely by
identifying information that needs to be obtained. Depending on the size and environmental
conditions associated with the spill, the Incident Commander may have to report the release to
87
Ursa Operating Company LLC Oil Production Facility SPCC Plan
various state and federal regulatory agencies. For specific reporting information please see the
Colorado and Federal Verbal Notification & Written Reporting Protocol Table located in
Appendix B in addition to the Spill Prevention and Response Plan.
88
Ursa Operating Company LLC
3.5 Spill Response Training
3.5.1 Annual Training
Ursa and its contractors provide the following minimum training to oil-handlinq personnel
Operation and maintenance of equipment to prevent oil discharges;
Oil discharge procedure protocols;
Applicable oil spill prevention (State & Federal) laws, rules, and regulations;
General facility operations; and
The contents of the facility SPCC Plan.
Training is conducted prior to assignment of job responsibilities and then again annually.
Training includes oil spill prevention, SPCC Plan requirements, and federal and state pollution
prevention and spill reporting/response requirements.
3.5.2 Discharge Prevention Briefings
The facility conducts discharge prevention briefings for oil-handling personnel at least once a
year to assure adequate understanding of the SPCC Plan for the facility. At a minimum, this is
conducted via annual SPCC and spill response refresher training describing the contents of the
SPCC regulations and plans, spill response techniques, and a review of federal and state spill
reporting requirements. These briefings also include discussion of potential discharges or
component failures and precautionary measures. If a spill has occurred, Ursa will also
summarize the spill events and the measures implemented to prevent future releases.
3.5.3 Training Records
Copies of training and discharge prevention logs can be found in Appendix D. Training records
and Discharge Prevention Briefing logs are maintained for a minimum period of three (3) years
at the Rifle Field Office. Each contractor organizafion providing oil-handling personnel maintains
training records for its employees.
Oil Production Facility SPCC Plan
a
89
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION.
Ursa Operating Company LLC Appendix B
APPENDIX B
OIL SPILL CONTINGENCY PLAN
AND EMERGENCY RESPONSE
PLAN
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Ursa Operating Company LLC Appendix B
Oil Spill Contingency Plan
This Oil Spill Contingency Plan (Plan) was prepared in accordance with 40 CFR I12.7(a)(5) to
address discharges of oil from the facilities covered by the Spill Prevention Control and
Countermeasure (SPCC) Plan. It also addresses oil discharges from fìeld operations where
secondary containment is impracticable, per 40 CFR 112.7(d). This Plan complements the
prevention and control measures presented in the SPCC Plan by defining procedures and tactics
for reporting and responding to discharges of oil.
The Plan is intended to protect the public and minimize damage to the environment by providing
a timely, efficient, coordinated and effective action plan to respond to oil discharges. The plan is
consistent with the National Oil and Hazardous Materials Pollution Contingency Plan and
follows the guidelines provided in 40 CFR 109.
40 cFR 109.5 a Definition of the authorities,lities and duties of all
Ursa Management is responsible for
Ensuring the necessary resources for control and cleanup are available
Ensuring that personnel are adequately trained to notice, report and respond to oil
discharges
Ursa's Field Superintendent (or designate), serving as the Incident Commander, is responsible
for:
Overall coordination of the control and cleanup of the oil discharge
Committing the necessary resources (including monetary)
Requesting additional assistance from outside contractors andlor the Federal authorities
if necessary
Ensuring repairs are made prior to putting equipment back in service
Ensuring that proper notifications are made to Federal, State and Local agencies,
including any follow up documentation
Providing site safety plan if necessary
Coordinating disposal of contaminated material
Being familiar with the SPCC and Oil Spill Contingency Plans
Being alert for oil discharges and responding to them as appropriate
Assisting, as required, in the control and cleanup of the oil discharge
40 CFR 109.5(b) Establishment of notification cedures.
Ursa owns and operates a number of oil production facilities located in Garfield County,
Colorado. Personnel are trained to look for and report any oil discharge. The following is a list
of emergency contact numbers. Depending on the size and nature of the oil discharge some or
all of these contacts will be notified. Please refer to the flow charts and tables on the following
pages for spill response and notification protocol.
Ursa Operating Company LLC
ffiUrsa ;, , Colorado Operations
INCIDENT NOTIFICATION & MANAGEMENT PROTOCOL
(H&S INCIDENTS, SPILI.f¡, ENVIRONMENTAL/PROPERTY DAMAGE, NOVS)
Appendix B
If MAJOR INCIDENT AND NO
DIRECT COMMUNICATION, KEEP
CALLING DOWN THE CHAIN - NO
MESSAGES or EJVTAILS
VERBAL NOTIFICATIONS
(Person Discovering I ncident)
PRODUCTION
Shane Vaughn
OPERATIONS
Matt Honeycutt
CONTRACTOR
INCIDENT? NOTIFY
RESPONSIBLE
CONTRACTOR
IMMEDIATELYHans Wychgram Pake Younger
MAJOR INCIDENT
'H&S Rêcordable lnc¡dsnt
'Roportabls Splll / lncident
'NOV W Potentiãl F¡nes-Spill Off-Pad
'Spill to Live \A/atÐr
'Med¡a lnquìry Possiblê
'Property Damage
'Landûwner Complaint
IMMEDIATE REPORT
TO ENVS
REG
'
ENVIRONMENT
Rob Bleil
LAND
Jefi Pc¡¡vers
H&S
Tara Mall
SAFETY/¡NJURIES
TOP PRIORITY INCIDENT MANAGEMENT
DISPATCH EMERGENCY,
INCIDENT & SPILL RESPONSE
CREì¡¡S APPROPRIATE
FIRE / SERIOUS INJURY I
VEHICLE ACCIDENTS
LIFE THREATENTING?
{lmplement SSERP)
LAND
'
PROPERTY
DAMAGE
PROPERTY DAMAGE
/ LANDOWNER
COMPLAINTS 'WATER WELL
CONCERNS
LAND RESOLVES wlTH
RESPONSIBLE PARTY &
LANDOVUNER
REG
'
ENVIRONMENT
SPILLS/ RELEASES
(lmplement Splll Response
Plan) Notlfy Splll Coord¡nator
ENVIRONMENT /
NATURAL RESOURCES /
WLDLIFE IMPACTS
(Resolvewjops Leadsl
NON.COMPLIANCE /
FAILED AGENCY
tNSPECTIONS & NOVS
(Resolve wl0ps Leads)
H&S
OSHA FIRST AID /
REPORTABLE INJURY _
TREAT & REPORT
NEAR MISSES - REPORT
IF FUTURE RISK OF
SERIOUS INJURY/ LIFE
THREATENING
REG I ENV / H&s (Gell)
R.,Blell (R/E) (7æ) 4?+0303
SPILL PROGRAM LEAD
K. Rçwe (S70) 261-æ15
OPERATIONS {Gtll Phone}
M.Honeycutt (970) 81 2.21 98
s.Vaughn (s70) 623',953s
P.Yornser (S70) 260-2423
H:ìArydrgram (303) SBí-S079
H&S
T. Mâil {970) 61e2155
NOTE: MEDIA INQUIRIES SHOULD BE DIRECTED TO DON SIMPSON
LAND (cÞlll
J. Powers (970)309"9359
MEDIA/COMMUNITY
D. Sjrnpern (?91) 467-3117
Ursa Operating Company LLC
WUt'sa'Bo,l#i.'.." c'orcdo operations
SPILL RESPONSE PROCESS
Appendix B
See Appendix C - Spill Notifcation Protocol
I
Proiad Closure
SPILL DISCOVERY
Notify On-S¡te Supervisor
Contáin and/or control spill if safe Closs valvês or stop/redirect low
to prevent sp¡ll from geting larger
See Appendix BCompletê Upper Shaded Sect¡on of
Ursa lncident lnvestigation Form
Notify Ursa
Ops Lead
Coritact Sp¡ll Program Lead
K. Roure (HRL)
coGcc
LEPC / Firs Chief
CDPHE
Regulatory Agency Notifi cat¡ons
Responsiblê Pady DÊtê rmination
Contracior Ursa
Remediation ln accordance with
Section Vl. D.1
Waste Manaoemênt
ln accûrdancê with
Section Vl. G
Corrective Adion /
Training
Documentation to
Regulatory Agencies
Wastê Manaqement
ln acôordanre with
Section Vl. G
Conêctive Action /
Training
Remodiationln aæordance urith
Sêct¡on Vl. D.2
Documentat¡on Copies
to Ursã
Proiect Closure
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Ursa Operating Company LLCCOLORADO AND FEDERAL VERBAL NOTIFCATION & WRITTEN REPORTING PROTOCOLFootnote:l. Notification and reporting requirements that are listed above are for the most common chemicals encountered in day to day Ursa operations.2. For chemicals not listed, consult the MSDS for the chemical of concern or call an Ursa env¡ronmental team lead.3. Reportable quantities that are reported by weight need to be converted to a barrel or gallon equivalent for Federâl reporting and notification requirements.4. NotiS the State Highway Patrol for transportation related spills involving hazardous materials.5. Notify the Bureau of Land Management for spills on federal lands as applicable above.Appendix BLEPC / Fire ChiefwrittenReoortinsUponRequestNone Emergency E-mailWithin 24 hoursUponRequestN/AN/AN/AUponRequestUponRequestUponRequestUponRequestVerbalNotificationImmediatelyImmediatelyN/AN/AN/AImmediately72hr email72hr emall24hrNRCÆPAWrittenReportingUponRequestN/AN/AN/AUponRequestN/AN/AN/AUponRequestUponRequestN/AN/AVerbalNotificationImmediatelyN/AN/AN/AImmediatelyN/AN/AN/AUponRequestUponRequestN/AN/ABLMWrittenReportins15 days15 days15 days15 daysI 5 days72hrsN/A15 daysl5 days72 hr (email)15 days (NTL-3A)72hr (email)15 days (NTL-3A)1 5 daysVerbalNotificationImmediately24hrs24fus24btsImmediatelyN/AN/A24hrsImmediatelyN/AN/A24hrsCDPHEWrittenReoorting5 DaysN/AN/AN/A5 days5 Days55 days5 days5 days55 days55 days55 days5VerbalNotifrcationImmediatelyN/AN/AN/AImmediately24 hours24hrs24 hoursImmediately24 hrs24hrs24 hrsCOGCCWrittenReporting10 DaysInitial Report - 72hrsForm 19 - 10 DavsInitial Report - 72hrsForm 19 - 10 DavsInitial Report - 72hrsForm 19 - 10 DaysUpon RequestN/AN/AN/AN/AN/AN/AN/AVerbalNotificationImmediately.24h¡s24hrs24 hrsImmediatelyN/AN/AN/AN/AN/AN/AN/AMinlmumAmountto ReportAny1 bbl orgreater5 bbls. orgreater>100 bblsAny>25sallons> 420 gal(10 bbls.)> 4,200gal (100hbtìAnyReportableQuantity(RO)<RQ but>10 bbls.<RQ but>100 bbls.MediaAffectedSurface waterGroundwaterSoil -OutsideContainmentSoil -InsideContainmentSurface waterGroundwaterSoilSurface waterGroundwaterSoilChemic¡lE&PNon E&PHydrocarbonBasedNon E&POther
Ursa Operating Company LLC Appendix B
Spill response shall be completed in accordance with the Ursa Spill Response Plan.
The follôwing pages contain phone numbers for contractors, regulatory agencies and
local emergency contact entities.
Water Haulers and Misc.
T.D. Productions
(970) 230-0704 (Terry Dick)
(97 0) 23 0 -0702 D ispatch
o70\ 984-2218
Wild Well Control Inc (281) 3s3-s481
Hoeback (970\ 309-6322 (24/7)
Redi-Vac trucks
(970) 625-0233 office
O70\ 7561277 cell Lucas Gallegos
Dalbo
(970) 625-0431 office
O70\ 625-8659 cell Audie Williams
Cascade Tanks (Mountain Water)(970) 948-7262
Mountain Valley O70\ 948-7262 cell Branden
Speedy
(970) 98s-9248 Office
(970) 309-8154 Cell Tracy
J&A Services
(970) 434-9435 Travis Payne
O70\ 590-4560 Cell Travis Anderson
Rain for Rent (970) 625-4600 offrce
'Well Watchers (970\ 309-7 313 Cell Dan Mc queen
R&WBOP (970) 255-6487 Office
Mountain States Pressure Control (307) 362-1903 Office
Cudd Well Control
(970) 858-8230 offrce
(970) 778-5553 cell Allen Bourseois
Advanced Oil Field Services O70\ 625-9704 office
Flint Energy (970) 625-4265 offtce
Calfrac - Kathleen Neault, HSE Supervisor
(970) 243-7812 office
(970) 985-8613 cell
Frontier Drilling - James Lynch, Safety
Manager
(43s) so3-s767
Ursa Operating Company LLC Appendix B
ÄGENCY CONTACT NUMBER Ð-Mail ADDRDSS
Local and State Asencies
Parachute Fire Chief David Blair 970-285-9t19 (o)
970-250-9851 (c)firechief@gvfpd.org 0124 Stone Quarry Rd.
Parachute, CO 81635
Rifle Fire Chief
Chad Harris 970-625-1243 (o)
970-379-9681 (c)Chad.Haris@crfs.us 1850 Railroad Ave.
Rifle, CO 81650Silt Fire Chief
CDPHE Bob Peterson
John O'Rourke
970-248-715 l(Bob)
719-269-5327 (Iohn)
I -877-5 1 8-560 8 124-hr"l
Robert.Peterson@dphe. state.co.us
of
John.Orourke@state. co.us
4300 Cherry Creek Drive South
Denver, CO 80246
CDNR Assigned at call l-800-536-5308 Assigned at time of call 1313 Sherman Street, Room 718
Denver, CO 80203
CO Dept. of
Transportation Mike Verkitus 970-216-0577 Mike.Verketis@dot. state. co.us 222 Sotth6th St. Room 100
Grand Junction, CO 81501
COGCC Carlos Lujan (970)-625-2497 or
(303) 8e4-2100 Carlos.Luj an@state.co.us
I120 Lincoln Street, Suite 801
Denver, CO 80203
Garfield County
oEM (LEPC)Kirby Wynn (970) 94s-0453 kwynn@garfreld-county.com
Kirby Wynn
107 8th Street
Rifle, CO 80751
Garfield County
Health Agency Morgan Hill (970) 625-5200 ext 8 106
970-379-3826 mhill@garfi eld-couny.com 195 W. l4th Street
Rifle, CO 81650
Pitkin County OEM
Alex Burchetta
of
Cindy Mohat
970-920-5037 alex.burchetta@pitkinsheriff. com
Cindy Mohat
Emergency Management Cord.
Pitkin County sheriff s Office
506 E. Main
Aspen, CO 816ll
Silt Public Water
Intake
Jack Castle
Or
Gerry Pace
970-87 6-2353 ext 8 I 7
970-876-5444
970-876-0460
jackc@townofsilt.org
231 N. 7ú Street
PO Box 70
silt, co 81652
Rifle Public Water
Intake Diik Deussen 970-665-6590 ddeussen@rifleco.org 202 W. Railroad Av
Rifle, CO 81650
Parachute Public
Water Intake Mark King 970-285-7630 (office)
970-986-1821 (cell)mking@parachutecolorado. com
222 Gtand Valley Way
PO Box 100
Parachute, CO 81635
Federal Asencies
National Response
Center Assigned @ Call l-800-424-8802
Available 24 hours
HQS-DG-lst-
NRCINFO@uscg.mil
2703 Martin Luther King Jr Ave.
SE, STOP 7713
Washinston. DC 20593-7 7 13
US Dept. of
Transportation Assigned @ Call (202) 366-4000 N/A 1200 New Jersey Avenue, SE
Washington, D.C.20590
Environmental
Protection Agency Assigned @ Call (202) 272-0167 N/A
Ariel Rios Building
1200 Pennsylvania Ave., NW
Washington, DC20460
Bureau ofLand
Management Jim Byers 970-876-9056 (o)
970-319-2532 (c)jbyers@blm.gov 2850 Youngfield Street
Lakewood, CO 80215
Ursa Operating Company LLC Appendix B
40 CFR 109.5(c) Provisions to assure that full resource capability is known.
All field operation personnel are familiar with the location of spill response equipment and
response strategies, and with the SPCC and Oil Spill Contingency Plans. They receive annual
training in the deployment of response material and handling of hazardous waste
(HAZWOPER).
Suffïcient equipment to respond to the majority of oil discharges is kept at the Ursa Field Office
and is accessible 24-hours a day to field operation personnel. This equipment is veriflred on a
monthly basis by designated personnel and is replenished as needed.
Ursa Operating Company LLC
Identiflrcation and Inventory of Recommended Applicable Equipment
3-Cases
1-Case
1-Case
1-Case
1-Roll
1-Bundle
1
6
2-Rolls
2-Rolls
J
I
2
1
17" x19" x318" Oil absorbentPads
7" W x 15" L Oil Absorbent Pillows
3" x4'Mini Booms
3" x 8" Oil Absorbent Booms
5" x l0' Oil Absorbent Boom
36" x 56" 3 mil Trash Can Liners
Large Tyvek Coverall
Extra Large Tyvek Coverall
Size 10 Green Nitrile Gloves
Round Point Blade Shovels
Square Point Blade Shovels
5-l/2 foot Steel Fence Posts
Fence Post Driver
16 ga Tie Wire
Wooden Stakes
Crescent 148 Piece Tool Set
28" Traffic Cones
Duct Tape
6 mil20'x 100' Plastic Sheeting
20 lb. Fire Extinguishers
Metal First Aid Kit
55 Gal. Poly Drums (Drums contain absorbent booms, pillows and pads)
55 Gal Steel Drum
Appendix B
1
2-Boxes
1
1
l-Bag
2
2
t5
1
40 CFR 109.5(d) Provisions for well-defined and specific action to be taken after discovery
and notification of an oil discharge.
Ursa has the primary responsibility to provide the initial response to oil discharge incidents
originating from its operations. To accomplish this, Ursa has designated the Regulatory and
Environmental Manager, Robert Bleil, as the qualified Incident Commander. Taru Mall will
serve as the Alternate Incident Commander. In addition, Ursa maintains an Emergency
Response Team, some or all of which may be mobilized depending on the size and nature of
the oil discharge.
Upon the discovery of an oil discharge the Incident Commander will be notified so that
appropriate action can be taken. The Incident Commander has the authority to direct and
coordinate response operations and may request assistance from Federal authorities as
necessary. Containment and clean-up operations will be managed out of the Ursa Field Office.
Operations personnel are equipped with cellular phones to assist with communications.
In the event of a discharge, the first priority is to stop the product flow and to shut off all
ignition sources, followed by the containment, control, and mitigation of the discharge.
Specifically, the following response procedures will be implemented in accordance with the
respective personnel's level of training:
B. Assessment and Notihcations
Ursa Operating Company LLC Appendix B
Response Procedures
Please refer to the Spill Prevention and Response Plan for a definitive guide for response
procedures.
A. Detection:
Notify the Incident Commander that an oil spill has occured þrovide location,
source, amount, nearby areas of concern, etc.).
Shut off ignition sources (motors, electrical circuits, open flames).
Turn off pumping unit that charges or provides flow to the flowlines.
Locate the source of flowline leak.
Attempt to stop the source of the leak, if it can be done safely.
Initiate containment.
Investigate the discharge to assess the actual or potential threat to human health
or the environment.
Mobilize the Emergency Response Team if necessary.
Request outside assistance from local emergency responders, as needed.
Communicate with property owners regarding the discharge and actions taken to
mitigate the damage.
Make appropriate notifications to Federal, State, and Local agencies.
C. Control and Recovery
Prevent the spread of oil by deploying absorbents (i.e. booms), by building
diversion structures (i.e. berms), or digging temporary containment pits.
Direct clean-up of the oil and oil contaminated material.
Arrange to have soil andlor water samples analyzed per COGCC Table 910-1
standards, andlor CDPHE water standards. If contaminants are below the affected
agencies allowable concentrations cleanup is complete.
Containerize contaminated material (soil, water, absorbent material, etc.).
D. Disposal of Recovered Product and Contaminated Response Material
1
2
aJ
4
5
6
2.
3.
2.
aJ.
2
aJ
4
5
1
4.
1 Recovered product can either be added to another tank or disposed of at an
appropriate disposal site.
Properly characteÅze, label and store all contaminated material.
Dispose of contaminated material in accordance with all applicable solid and
hazardous waste regulations using a licensed waste hauler and disposal facility.
Ursa Operating Company LLC Appendix B
E. Termination
Arrange for necessary repairs to equipment or flowlines.
Review circumstances that led to the discharge and take necessary precautions to
prevent a recurrence.
Submit any required follow-up reports to the authorities.
Update the SPCC and Oil Spill Contingency Plan as necessary.
40 CFR 109.5(e) Specific and Well Defined Procedures to Facilitate Recovery of Damages
An Environmental Incident Report will be filled out by the Incident Commander and maintained
on file at the Ursa Field Office. Any other documentation regarding the oil discharge will also
be kept on file.
1.
2.
J.
4.
Ursa Operating Company LLC
APPENDIX C
DISCHARGE NOTIFICATION FORMS
. COGCC Form 19 Spill/Release Report. [.Jrsa's Environmental Incident Report. Submittal of Information to Regional Administrator for Reportable Discharge(s)
Appendix C
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Ursa Operating Company LLC
FÔRM
1g
R€o t¡Sg
4lldc hr¡e lo,r¡s¡t fçrm
Stdc of Golorado
Oil ard Ga¡ Conssrvation Commission
Form 19
FOR.OGCC USE QNLY
sþill reportlal(en þy
FAÈILITY IÛ:
fir-ffi,ffi112û Lincoln 61Íeel, Suite 801, DenvBr,Cr,lorado S0203 (303)894-21û0 Fax:{303)å94-21ûü
SFILL/RELEASE REPORT
DESCRP]NON OF SP¡LL OR RELEASE
CORRESTIVE ACTION
DEécriþÈ immedlás lusponse thour stopped, containe{ and recor¡erÞd}l
0EsÊribe åny emergemy pils constructed:
Hot^j üE$ the extêrìt 0l contårTiinallon determined:
FurlhFr rernediãll0n aclirilies proposed ,Ëttåçh t€pðratÊ .sh94 lt nÈeded)l
DegclþB tÍteasures taken lo prei,enl pmlllem lrûm reoccurring:
OTHERNOTIFICATIONS
Loral
Buhmil â gile lndes{igail0n ahd Retïedialion WÐrkplan (Form 27} \A'tìen requested þy the Dlrecl0l,
?0þe.rBþûrtâd as 800n a
I[iÊt fiu e bbls muÊt bÊ
BTbeby
s þveùpractany Bpillicãblã;ofthslvãtÊrg mustÉtatewhirhreleasemaYlmFärt
wilhin tenreporled daye.bbls be ûithin hours allåndmustreponBd2{spifls
Phone l.hffbers
¡.,lot
Faxì
l¡ddress: _
tgCC 0perãt6r No;
S'lale:_ Zrp:city:
contêrl Person:
NamÊ ú opeËlôf
firqtr:
-
Êecllon:-
lotünshiti: Ranue:
Merldian;_
üounty:
API HurTrber._
Sperily r,Elume spflled and rÊcouelsd {n.blrl3) for te tollotiing malerlâls.
ßil spifled:
-
0ll rscovd: -. WatEï sp¡llÉd: --llüater rscolld:
-
ÕlhÞr spllled:
-
other Þcovd;-
ßrûund llüãter lmF8cled? D Yar I tlo gwfåce Wãter hìpac'tsd? [ ves flNo
turËfd lånd use:- - Wssther tondilion,$.
-
Sûil fgeoloqy desc riplionì
--lFIESSTllÀllÂìlllÇrepatdistance INFEETIo nearesl,.,. gurlÊcetïatÉrl-- ruellands;--buildings;
-
t¡véstolk:
-
i,ìElet ü,efls:
-
Dépth t0 $hðllowesl gr0urld $Eler;
Cåuse d spill (e.9., equipment lallure, humån erEr, etc.);
-
Delailed descr¡pt¡on Êl lhe sp¡ll/telèase hcidehtl
DÊtÊ ûf lnciden:
-
Facility Nams 8.N0.
Tlpe 0f Fsr¡llty (li,e[. tánk þBttÊry, tlohJ linÈ, pit):
lltlell Name and Nmber:
Arsa and vÊrticâl sxtÈnt d splll-Codalned ûìi'ilhin benì? E Yas E No
AænTY (hfil¡ft Fhons boonse.DðIS
SpillrRdme Tradrin g No:
Ursa Operating Company LLC
ffiuFsaiPåffiilri\e
Contractor Spill/Release Report
)ad/Location:
ìeport Date:
CONTRACTOR SPILURELEASE REPORT coNrRACroR:
ENVIRO,N MENTAL S PILLTR ELEASE INVESTI GATI OIII-COLO RADO OPERÁ flO^ls
Orreêd: Îm: Dl{dèrêd tV! toiÞâny:
INCIDENIlYPÊ RTIf,AST TYPE UIND9AFFECIID MTDIAAFÍTCTED BIOTAAFFECfED
I
(
Facil¡ty
TÈnspfftatim
( | E&P Wäsrè
| ¡ Non- E&P
Privâte
Fedeôl
State
Nffe
Pl ent5
wildliTe -6âñê
wildlifê - T&t
Air
Watérs (U.S)
Wetlând/R¡perte
6ruñd wâtêr wildli{e-
( ) other:{ I other:| ) on-t-ease
I ) oft- Leæe
ÍHRËATTO HUNNANS OR No YES -
lñICIDENT DESCRIPTION (How iñcident occurêd, type ôf effluent, emissitrs, cheñicâ|, etc.):
ESTIMATED VOTUME/qUAilNTY OF RELEASE:
I,OIUME REMAI'{ING FOR I/IIÂSTE MGMT¡
lvotuME REcor/ERED:
RESPOIISIBIE PARTY:
COMPANY ENV. REP:PHONE:EMAIL:
ROOTCA1JSE
coRnÊcrnÆAcnoN
COTIFIRMED:
TEMPORÄRY STORAGE LOCATION:
DtsPostTloil of wAsTE
TO IMPI.EMEI{T ADI)ITIONAL DATE:
Signature (Env. Rep)DatÊ:
THIS REPORT MUST BE FITED AND SUBMI'TTED WITHIN 24 HOURS
OF THE INCIDENT TO THE URSA SPILL COORDINATOR
Ursa Operating Company LLC EPA Reportable Discharge Notification Form
Submittal of Information to Regional Administrator for Reportable
Discharges
In the event of a reportable discharge or discharges, this page can be utilized to provide official
notification to the Regional Administrator. If the Facility has had a discharge or discharges which
meet one of the following two criteria, then this report must be submitted to the Regional Administrator
within 60 days.
This Facility has experienced a reportable spill as referenced in 40 CFR Part 112.1(b) of 1,000
gallons or more.
This Facility has experienced two (2) reportable spills (as referenced in 40 CFR Paft
112.1(b) of greater than 42 gallons each within a 12-month period.
Facility Name and Location:
Facility contact (Name, Address, Phone Number)
Facility maximum storage or handling capacity:
Facility normal daily throughput:
Describe the corrective action and countermeasures taken (include description of equipment repairs and
replacements)
Describe the Facility (maps, flow diagrams and topographical maps attached as necessary):
Describe the cause of discharge(as referenced in 40 CFR Part 112.1(b)) including failure analysis of the
system:
Describe the preventative measures taken or contemplated to be taken to minimize the possibility of
recurrence:
Other pertinent information:
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION.
Ursa Operating Company LLC Appendix D
APPENDIX D
SPCC FORMS
. SPCC/ContainmentFieldlnspection. Personnel Training Log
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
LOCATION F'Itr LD DATE
t,
TAN KS/ PIPING/EQUIPMENT Y N SECONDARY CONTAINMENT Y N
Tanks - Evidence ofleâks on tæ¡ks,
seams, connections?
Evidence of damage to containment
infrashucture?
Tanks - NFPAlabels absent or
damaeed?
Evidence of containnent not being
frmctio¡ral?
Piping - Evidence oflealc on pipes,
c onnectioris, valves fi ttings?
Evidence oftank product r¡ithin
containment?
Loading/unloading - Evidence of
improperly secured connections?
Eviderrce of mowmelt / rainwater within
containmerú?
Other - Evidence of leakVspills from
other equipment?
Evidence of hash / debris within
conlainment?
SPILLS & RELEA,SES Y N
Ta¡rks - Evidence ofspìlls or releases to the enviroûnent?
Piping - Evidence ofspills or releases to envirortment?
Loading / Ur¡loading - Evidence of spills or releases to envi¡onment?
Protluced Water and Condensate Tank Information Miscellaneous ent and
Tank ID Tank Contents Tank Volume
lbbt.l Miscellaneous Quantlty Volurne
Sepaf,ators
Oil (eallons)
Fuel (eallorß)
Frac Ta¡lks
Other Chemicals':
ìf! I
^
300 Series Rules Y N
Is the location within a 3l7B area?NA
Per 0l.17 .2t14 correspondence with COGCC, ¡efer to
notification that nrles have been finalized is provided.
the specified regrfatiorrs until CocCC - 605.a.(a),
906.e.(l )
600 Series Rules Y N Regulatlon
Is tïe facility within a setback zone?NA
For Exception Zone Setback locations within 500 feet and up gradient of
a surface water body, tediâry coÍtairunenlis required
farilities. If applícable, is the site in compliance?
morurd production cocCC - 60a.c.(3),8.üi.
For Urban Mtigation Area Exception Zones, no more than two crude
oil or condersate tants ca¡r be within a single beml. Is the site in
complia¡rce?
CocCC - 604.c.(3).B.iv
A.ll Locaüons - Are seconduy coÍtafuünent features inrpervious?COGCC - 605.a.(4)
All Locâtions - Is the sylrthetic or ertgineered liner beneath each above
s¡oürd stomee tank?
CocCC - 605.a.(4)
9fi) Series Rulesz Y N
Alt Locations - Is the containment sufficient to hold the contents ofthe
la¡sest tânk ard ore cíoitation?
CoGCc - 906.e.(l)
¡
Onshore Order 3 Y N Comments
Do the wells or site access federal minerals?
Regulation not applicable
to orirrate leases.
are the seals pro'perþ placed on valves?
ffiUfSA :ffí,i spcciconrainment rnspection
Inspecto'r Name lnspector Signature
I Matoal s notregulaied ude 40 cFR 112
'¡ Secmda_v cm¡¿iãment that was cmsbucled befæ May 1, 2009 ø fedcal læd, æ before Aprll 1, 2009 on otl¡er lmd, shall comply wtth the ndes n.elfect
at ¡1e tiroe of @mbuctim Secûdry cmtainmenl constructed m tr aflerMay 1, 2009 on fedeml land, ø æ or afterlrpril 1, 2009 m otl6 land *¡all be
cmdructed ü indalled aromd all tanks contatning oil, cmdmsate, ø prcdrrced wata.
Ursa Operating Company LLC Appendix E
SPCC Training and Briefing Log Form
SPCC Training/Briefing Log
Trainer:
Date
Subiects Discussed:
Name and Signature:
Please note: briefings are to take place on an annual basis at a minimum. All oil handing personnel shall be
training in accordañce with the iriteria specified in 40 CFR 112.7(Ð(l). At a minimum, training is to
include:
a. the operation and maintenance of equipment to prevent discharges;
b. discharge procedure protocols; - (addressed during the Ursa Spill Response portion
of this training)
c. applicable pollution control laws, rules, and regulations; general facility operations;
and,
d. the contents of the facility SPCC Plan.
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Ursa Operating Company LLC
APPENDIX E
SUMMARY OF OPERATING PROCEDURES
FLOWLINE MAINTENANCE PROGRAM
Appendix E
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Ursa Operating Company LLC
SUMMARY OF OPERATING PROCEDURES
FLOWLINE MAINTENANCE PROGRAM
Before any pumper is on location, gas meters must be on and properly calibrated.
The following (however not limited to) need to be checked in addition to regular
pumper's responsibility to ensure a safe and normal operation by the production
operators/pumpers during their routine checks:
1. Water/oil dump valve and water flow meter malfunction:
A. Physically check every separator once every day by isolation/bleed-off
method.
B. If there is any leak through the dump valve and if it is large, replace the
trim or valve immediately, if not, try to flrx the problem on site as soon as
possible and plan to replace the trim/valve at the earliest opportunity.
C. Monitoring SCADA for gas & water flow rate can be used in conjunction
with physical check.
2. High/low setting trim troubleshooting:
A. Physically check Kimray valve for leak (by listening noise, feeling
temperature change on both sides of the valve and looking for frost for
high differential minor leaks).
B. If leak is suspected, confrrm by physically checking separator by blowing
separator down, then opening up to flowline to see if any gas is flowing
back into separator.
C. If leak is identified, replace high/low trim immediately.
3. Water/oil trim hanging open
A. Physically check every separator when on a pad by listening for gas
blowing through water/oil dump and visually check trim set position, then
rectify problem.
B. Periodically monitor separator pressures throughout day using SCADA to
detect discrepancies, then rectify problem.
C. Physically check by-pass valves for leaks by feeling temperature difference
on both sides of valve, look for, frost or noise.
D. If valves are leaking, take necessary actions and inform Ursa about its
replacement.
4. \ilater Skid Pressures at different areas in the field
A. Identify skid pressures that are higher than normal operating range on a
daily basis (use best judgment) and report to Ursa.
B. Purge gas from water headers to lower skid pressures.
Appendix E
Ursa Operating Company LLC Appendix E
5. Operation of Water Network during hydraulic fracturing & flowback using
the same system
A. When the field lines are being utilized for hydraulic fracturing (frac) &
flowback operations, the pump will be operated exclusively by the frac &.
flowback personnel. If you need to utilize any section of the network for
pumping into injection pads or pumping out from any pad to injection
pads, communicate this first to the fraclflow back personnel. For your
water needs at injection pads, coordinate this with frac/flowback personnel.
B. When there is no special operation, the network should be operated at
regular regime.
C. All operations (operation/cleaning and water pumping etc.) must be carried
out with the designated personnel and appropriate controls in place.
D. Finally, and most importantly, for any safety/environmental issues (e.g.,
spillage or leakages) immediately contact your immediate supervisor who
in turn shall contact Ursa and offer your best assistance to minimize the
impact from the incident to people, environment and assets. If your
immediate supervisor or Ursa personnel cannot be reached, p.lease refer to
the Emergency Contacts list in Section 3.4.I of this SPCC Plan for
alternate contacts. PLEASE DO NOT LEAVE A VOICEMAIL, talk to
the contact directly.
*Note: Atl of the above situations can also be identified through manually shutting
water skid off, and seeing if any gas is blowing to the production tanks
Ursa Operating Company LLC Appendix E
STANDARD OPERATING PROCEDURE FOR REMOVING
PRODUCTION WATER FROM TANKS
1. Pull truck onto the location
2. Inspect the location
3. Note unusual situations and report the issue to the dispatcher
4. 'Wear appropriate personal protective equipment: fire retardant clothing, hardhat,
safety glasses and steel-toed shoes
5. Plan an escape route, park facing the exit
6. When possible park as close to the stairs as possible
7. Observe the area for additional leaks, spills, releases, equipment damage, etc.
8. Gauge the tank.
9. Watch your footing and utilize the handrail
10. Attach the bondstrap as close to the unloading operation as possible
1 l. Connect the hose to the tank and the truck
12. Breakthe seal on the tank valve and record the seal number on the field ticket
13. Place the truck pump in the vacuum position
14. Open the valve on the truck first
15. Open the valve on the tank next
16. Ensure that the vacuum on the truck is operating properly
17. Open valve on the truck slowly
18. Remove material from the tank
While asing the clear site glass note when oil appears or when the tønk
domes ønd close the valve on the tunk
19. Open the bleeder valve (if present) on the load line
20. Pull material from the hose into the truck
21. lf the truck is too full, then push some of the material back into the tank so that the
hose can be effectively drained
22. Shutoff the pump
23. Gauge the tank again
24. Record the amount of material withdrawn from the tank and document results on field
ticket
25. Install new seal on the tank valve
26. Record the new seal number on the field ticket
27 . Disconnect the hose from the tank
28. Disconnect the hose from the truck
29. Collectremaining fluids in 5 gallon bucket
30. Inspect the hose, fittings and piping for damage
31. Properly place the hose in trays and secure all fittings
32. Replace the dust caps on the back of the truck valves
33. Remove the bondstrap
34. Leave copy of the field ticket for the pumper
35. Again, note any unusual occurrences
36. Leave location and drive to disposal site
1.
Ursa Operating Company LLC
STANDARD OPERATING PROCEDURE FOR PRODUCED FLUID
TRANSFERS TO TANKS
Initiat Tank Inspection - Valves and Overflow (Gooseneck) Caps
A. Prior to any fluid transfers, the water handling contractor will perform an
initial inspection of the tanks to confirm that all valves on tanks are closed
andthatthe overflows (gooseneck) have caps.
B. Initial inspection includes the valve which is located at the back of the
tank in front of the wheel axles.
C. All man hatches will be inspected to confirm that they are tight.
Initial Tank Inspection to ConfTrm Tank Fluid Levels
A. Prior to any fluid transfers, identify the full tanks and the empty tanks.
B. Tanks with closed thief hatches located at the top of the stairs are
considered full. These tanks can't accept produced fluids. All tanks with
produced water should have a closed thief hatch with a carbon blanket
installed.
C. Fluid Gauges Don't Work - Check tank status prior to pumping or
transfeming fluids.
D. Make sure that your tank has room before you begin unloading!
Visual Tank Inspection after Fluid Transfer Begins
A. Visually check each tank for leaks (valves, overflow/gooseneck caps)
immediately after tank filling begins.
B. Continue watching the tank until your truck is completely unloaded.
C. Tank fluid transfers are immediately stopped if a leak is found or tank is
overfilled.
Appendix E
Spill Reporting and Cleanup
A. If a spill occurs the contractor/driver will contact their immediate
supervisor.
B. Contractor will stop all fluid transfers during a spill event.
C. Truck driver will reverse his pump and begin vacuuming up the free
liquids that spilled if transfer by truck.
Final Inspection after Fluid Transfer is Completed
A. Confirm that tank flex hose is drained of fluids prior to disconnecting the
hose from the tanks - Do Not Drain Liquids on the Ground.
For pipeline fluid transfers, flex hoses must be left connected to the
manifold in front of the frac tanks - Flex hoses should not be disconnected.
Contractor will close the tank thief hatches on the tanks that are full to
prevent overfilling.
2
3.
4.
5.
B.
C.
Ursa Operating Company LLC Appendix E
FLOWLINE MAINTENANCE PROGRAM
Flowlines and piping at production facilities can be sources of releases. The quantity and rates
of such events will vary according to failure mode, operating pressures, current production
rates, and duration ofthe release.
Flowlines and intra-facility gathering lines and associated valves and equipment are
compatible with the type of production fluids, their potential corrosivity, volume and
pressure, and other conditions expected in the operational environment.
The majorþ of the piping in the field is constructed of steel and was installed in 2009 or
later. Flowlines are powder coated andlor painted. The steel lines all have cathodic protection.
The pressure lines operate between 0 to 600 pounds per square inch (psig), they were
designed for 0 to 1440 psig. Flowline construction materials are corrosion resistant to
condensate, crude oil, and produced water. Flowlines are sized appropriately for the flow
volumes expected at the facility.
Aboveground flowlines and associated appurtenances are visually inspected daily during the
pumper's regularly scheduled site visits for leaks, oil discharges, corrosion, or other conditions
that could lead to a discharge as described in 40 CFR 112.1(b). Inspection of conditions
associated with buried flowlines is accomplished by observing the ground surface above the
lines for evidence of leaks on a monthly basis. Records of the inspections are stored at the Rifle
Field Office and the corporate office in Denver. Buried flowlines are also inspected whenever
they are exposed.
Metallic lines have a cathodic protection system which is monitored once or twice a year as
deemed necessary. High density polyethylene (HDPE) lines are operated at or below the
recommended pressure and pressure tested on a regular basis to check their integrity. The
aboveground manifolds are inspected on a monthly basis for conditions, repair, painting, etc.
Appropriate corrective actions or repairs are made to any flowline, intra-facility gathering line,
or associated appurtenances if evidence of a discharge is present. Evidence of a discharge
includes product that has surfaced above the flowline. Suspected releases, including signiflrcant
loss of pressure in the line or significant reduction in product recovered in the production tanks
will be investigated.
In the event a leak is discovered, the lines will be replaced with pipe constructed of appropriate
materials. All repaired or replaced flowlines are pressure tested prior to being put into
operation.
Actions arc initiated promptly to stabilize and remediate any accumulations of oil
discharges associated with flowlines, intra-facility gathering lines, and associated
appurtenances.
Ursa Operating Company LLC Appendix E
Releases are reported to the appropriate superuisor and cleanup personnel upon discovery
Oil and impacted media are removed or remediated as soon as practicable.
Ursa Operating Company LLC
APPENDIX F
\MRITTEN COMMITMENT OF MANPOWER
Appendix F
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION
Written Commitment of Manpowero Equipment, and Materials
In addition to implementing the preventive measures described in this Plan, Ursa
will also specifically:
. Inthe event ofa discharge:
l- Make available all trained personnel and contractors to perform response
actions
ii. Collaborate fully with local, state, and federal authorities on response
and cleanup operations
- Maintain on-site oil spill control equipment.
. Maintain all communications equipment in operating condition at all times.
- Ensure that facilities are accessible.
Review the adequacy of on-site and third-party response capacity with pre-
established responsdcleanup contractors on an annual basis and update
response/cleanup contractor list as necessary.
Maintain formal agreements/contracts with response and cleanup contractors who
will provide assistance in responding to an oil discharge and/or completing
cleanup.
Rob Bleil. Regulatory and Environmental Manager
Name and Title:Signature
Date
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Ursa Operating Company LLC Attachment 1
ATTACHMENT 1
ONSHORE ORDER 3
THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION.
Ursa Operating Company LLC Attachment 1
Contents
1.0 Introduction.................
Table 1 . Well pads which are subject to the requirements of Onshore Order 3 .... '.L
Table 2. Specific wells which are subject to the requirements of Onshore Order 3 . Error! Bookmark not
defined.
2.0 Definitions.......................... 2
........................ 6
4.0 Seal Requirements 6
Figure l. An effectively sealed valve cannot be turned without breaking the seal.6
Figure 2. An ineffectively sealed valve, the wheel nut can be taken off and thus product removed........ 7
Figure 3. The yellow tag is a federal seal and is a designator of a violation. .'.."...7
Table 3. Non-LACT System Seal Requirements............... 8
Table 4. LACT System Seal Requirements.........9
5.0 SiteDiagramRequirements................. L0
Figure 4. Example diagram and valve documentation.........
3.0 Record Keeping Requirements ................
Figure 5. Example diagram of a LACT Unit
6.0 Site Security Inspection Requirements .........................
Site Security Inspection Form...........
7.0 Seal Tracking Requirements.......
Seal Tracking Form
8.0 Operator and Federal Contact Information
Table 5. Contact Information
9.0 Removal of Oil Requirements................
Removal of Oil Form..........
10.0 Theft or Mishandling of Oil Protocol.....
10.1 InternalNotificationProtocol
10.2 Federal Notification Requirements
Theft of Mishandling of Oil Form
11.0 Site Security Plan............
LL
L2
L3
t4
t7
L8
T9
19
......20
2t
22
22
23
24
Notification to Authorized Representative Form ............... 25
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Ursa Operating Company LLC Attachment 1
1.0 Introduction
Onshore Order 3 establishes minimum standards for site security with regards to
measurement and sales of condensate and/or crude oil for facilities located on all Federal and
Indian (except Osage) oil and gas leases. In addition, this regulation is applicable to all wells
and facilities on State or privately-owned mineral lands committed to a unit or
communitization agreement that affects Federal or Indian interests, notwithstanding any
provision of a unit or communitization agreement to the contrary. The following sections of
this attachment will provide the basic requirements for ensuring lJrsa's operations remain
compliant with the respective regulation.
This Order establishes the minimum standards for site security by providing a system for
production accountability and covers the use of seals, by-passes around meters, self-inspection,
transporters' documentation, reporting of incidents of unauthorized removal or mishandling of oil
and condensate, facility diagrams, recordkeeping, and site security plans.
Please see Table I and2 of this document for a list of well pads and specific wells which are
subject to the regulation. It should be noted that this list will serve as a living document and
should be updated when there is a sale or acquisition as applicable.
Please note that the BLM is responsible for compliance of Onshore Order 3 if a facility is located on
federal land. The BLM and USFS may coordinate efforts when a facility is located on USFS surface
land, but the BLM will retain responsibility per BLM Memorandum of Understanding WO300-2006-
07.
In order to ensure Ursa remains compliant with Onshore Order 3, personnel involved with oil
gauging, loading, and sales should be presented and trained with the required protocol per the
regulation. The two most important aspects to retain compliance are proper documentation
and ensuring valves are sealed effectively.
L
Ursa Operating Company LLCTable L. Wetl pads which are subject to the requirements of Onshore Order 31t This list is to serve as a living document and is to be updated as facilities are constructed or decommissioned.Attachment 1tFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalFederalBLMBLMBLMBLMBLMBLMBLMBLMBLMBLMUSFSBLMBLM-r07.s66292-107.541391-t07.535999-t07.473103-r07.6595s7-107.942184-t07.670354-r07.59413r-107.597724-107.599134-107.583039-107.s78976-107.55903339.46393r39.45500739.45850339.45457639.46010839.45628s39.35561239.52407839.44718439.52528139.4s6t4839.45617239.463162Castle Springs ECastle Sprines DCastle Sprinss'WCastle Springs QLBCF PadDixon Federal BFederal PABuckle A PadCastle Springs ACastle Sprinss VCastle Springs UCastle Springs TCastle Sprines B
Ursa Operating Company LLC Attachment I
2.0 Definitions
Becoming familiar with the below terminology will help ensure that the regulatory
requirements are fulfilled with regards to Onshore Order 3.
Authorized Officer - means any employee of the Bureau of Land Management (BLM)
authorized to perform the duties in Groups 3000 and 3100 of this title [43 CFR 3000.0-5(e)].
Authorized Representative - means any entity or individual authorized by the Secretary to
perform duties by cooperative agreement, delegation, or contract (see 43 CFR 3160.0-5).
Business Day - means any day Monday through Friday, excluding Federal holidays.
By-Pass - means any piping arrangement connected upstream and downstream of a meter which
allows oil or gas to continue on to the sales line without passing through the meter. Equipment
which permits the changing of the orifice place without bleeding the pressure off the gas meter
run shall not be considered a by-pass.
Effectively Sealed - means the placement of a seal in such a manner that the position of the
sealed valve may not be altered, or a component in a measuring system affecting quality or
quantity accessed, without the seal being destroyed.
Major Violation - means noncompliance which causes or threaten immediate, substantial, and
adverse impacts on public health and safety, the environment, production accountability, or
royalty income.
Oil - means all nongaseous hydrocarbon substances, other than those substances leasable as cole,
oil shale or "gilsonite". Please note that unless the oil is salable. the operator is not required
to maintain records of the loading/unloadins and seals. If the oil (i.e. condensatel
qcorrrnrrlqfe¡l wifhin the nroduced water nks hecnmes selahle- all renui rements for
documentation and record keepinq will applv.
Production Phase - means that period of time or mode of operating during which crude oil is
delivered directly to or through production vessels to the storage facilities and includes all
operations at the facility other than those defined by the sales phase.
Sales Phase - means that period of time or mode of operation during which crude oil is removed
from the storage facility for sale, transportation, or other purposes.
Seal - means a device, uniquely numbered which completely secures either a valve of those
components of a measuring system that affect the quality andlor quantity of the liquid measured.
2
Ursa Operating Company LLC Attachment 1
3.0 Record Keeping Requirements
All documents and records shall be filed for a period of seven years. The respective hardcopy
records shall be stored at the Rifle Field Office and shall be managed by designated Ursa
personnel as defined in Section 8.0 of this document. Inthe eventan acquisition is made andno
records are avatlable, a document stating such shall be drafted and hled for the respective
location.
4.0 Seal Requirements
Specified equipment components will be required to have a seal as defined in Section 2.0 of
this document. The seals will be placed and removed by designated personnel at the time of
sale, or during a change in the position the respective valve is kept (i.e., open or closed).
Anytime a seal is changed, it shall be documented in the applicable forms included within this
document. Each ineffectively sealed valve or appropriate valve not sealed shall be considered
a separate violation. Violation fines range from $250 to $500 per violation. In the event an
authorized representative identifies the unsealed valve, he or shall place a federal seal on the
valve and notify the operator. Fines for theft of materials (and/or lack of royalty payments) are
much greater. The seal record (Section 7.0) serves as the operators defense against such fines
in the ðase thàt atheft does occur. Please see the below figures for examples of seals2:
Figure 1. An effectively sealed valve cannot be turned without breaking the seal.
)i t.-:èÞ.,þ.i. f!
- /:Ú|/ilæ!c:
¿-'¿*-'jril-
rÌ ñ.{rf
'ù
1 r t''Ð
-|
'Figures taken from BLM Bakersfreld Training document.
6
, *d
Ursa Operating Company LLC Attachment I
Figure 2. An ineffectively sealed valve, the wheel nut can be taken off and thus product
removed
Figure 3. The yellow tag is a federal seal and is a designator of a violation.
F
f¡t.
t\
Tr
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I
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.
I
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I
7
Ursa Operating Company LLC Attachment 1
The following Tables (3 and 4) provide guidance with regards to the equipment which is subject
to the seal requirements. Any exceptions or additional guidance is included in the right hand
column.
Tabte 3. Non-LACT System Seal Requirements
The above seal requirements will be applicable to most well pads to a certain degree. The seal
requirements for the LACT units are specihed in Table 4 on the following page. The LACT
Units are a much less common facility.
8
EQUIPMENT REQUIRING SEAL EXCE,PTIONS, NOTES
NON-LACT SYSTEMS
Sales Valves
The valves shall be effectively sealed during the
production and sales phases or combination of sales
phases.
Circulating Valves
Drain Valves
Fill Valves
Equalizer Valves
Any valve which provides access to oil
prior to measurement for sales.
All lines entering or leaving oil storage
tanks
Exempt: Valves on production vessels (e.g. gun barrel,
wash tanks)
Exempt: Valves on produced water tanks, provided
access does not exist through a circulating drain or
equalization system to production and sales tanks
Exempt: Sample cock valves with piping of I inch or
less in diameter
Exempt: When a single tank is used for collecting
small volumes of condensate, all other requirements
apply.
Exempt: Gas line valves of 1 inch or less used as tank
bottom "roll" lines, provided there is no access to the
contents ofthe storage tank and said lines cannot be
used as equalizer lines.
Exempt: Tank heating systems which use a fluid other
than the contents ofthe storage tanks.
Exempt: Tank vent frll valves
Ursa Operating Company LLC Attachment I
Table 4. LACT System Seal Requirements
LACT systems
Sales or equalizer lines do not need to be
sealed. However, any valves which allow
acoess for the removal of oil prior to
measurement through the LACT system shall
be sealed. There shall be no bypass around the
LACT unit.
NoneSample Probe
NoneSampler Volume Control
excluding the safety pop-off valveAll valves entering or leaving the
sample container
None
Meter Assembþ, including tho counter
head, meter head and automatic
temperature compensator
NoneTemperature recorder
Back pressure valve downstream of the
meter None
NoneAny drain valve in the system
NoneManual sampling valves
9
Ursa Operating Company LLC Attachment 1
5.0 Site Diagram Requirements
¡ Accurately reflects the relative position of the production equipment, piping and
metering systems - does not need to be to scale.
. Commencing with the header, identify the vessels, piping, and metering systems
located on the site and shall include the appropriate valves and any other equipment
used in the handling, conditioning, and disposal of oil. gas, and water produced,
including any water disposal pits or emergency pits. In those instances where pits are
co-located, such pits may be shown in parentheses on the facility diagram.
o Indicate which valve(s) shall be sealed and in what position during the production and
sales phases and during the conduct of other production activities, i.e., circulating
tanks, drawing off water, which may be shown by an attachment, if necessary.
¡ Require as an addition. when describing co-located facilities operated by 2 different
operators, a skeleton diagram of the co-located facility, showing only equipment. For
co-located common storage facilities operated by I operator, one facility diagram shall
be sufficient.
o Be filed within 60 days of completion of construction of a new facility or when existing
facilities are modified or when a non-Federal facility is included in a Federally
supervised unit agreement or communitization agreement.
o Clearly identiff the lease to which it applies and the location of the facility covered by
quarter section, section, township, and range or by a legal land description, with co-located
facilities being identified by each lease and its facilities.
. Clearly identify the site security plan covering the facility.
10
Ursa Operating Company LLCFacility Name:Location (legal or latllong):Lease #:Figure 4. Example diagram and valve documentationAttachment 1t,!ÊhGeneral sealing of valves, sales by tank gaugingOther Phase (e.g. drainingfrom S/T l)Fl Sealed F2 - F4 Not SealedEl Sealed E2 -F.4 Not SealedSealedDl Not Sealed DZ -D4 SealedSales Phase (e.g. from S/T 1)Fl Sealed F2 -F4 Not SealedEl Sealed E2 -E4 Not SealedS1 Not Sealed 52 - 54 SealedSealedProductionPhaseNot SealedNot SealedSealedSealedValve IDFill Valves F1 - F4Equalizer Valves El -F4Sales Valves Sl - 54Drain Valves Dl - D4prr(3'9¡71tll t,tt ttlî1l
Ursa Operating Company LLCAttachment 1Figure 5. Example diagram of a LACT UnitrrÉsstt'lE o^GGsrâÀ|fle iAln cLtnrtü^Î('e3 ¡ w rñot€ËCCË¡fÌnC 3ïe6g ,*aatS^¡.'tC l}'lotGcErferrrû^L lrå."./SAr.tLEnGlrE{¡X VÂrvË3Â.¡9tË coirY^ilcñrrxtre 3ï3TCroff,¡Atlc¡æsi^cl(Ytw:ËúG'tËt}JrËt¡rl(}rrÉtLrlñor'tr YALVÊSorv€rTct v^rv€"oÊn¡AC(riüs!5uæ vALtrEß I W.ra¡.rÌoRgtãcal¡æt F^ilÊr;ñolËee|'oc* YAtviË12
Ursa Operating Company LLC Attachment I
6.0 Site Security Inspection Requirements
Ursa shall establish an inspection program for the purpose of spot checking their facilities
with regards to compliance with Onshore Order 3 requirements. One location a month
shall be inspected with the form included in this Section and cross referenced with the seal
tracking form (Section 7.0) to verify the information. Any information which does not
cross reference properly will be flagged and investigated. Pending the results of the
investigation, notification may be provided to an authorized representative and will be
documented and filed for later reference.
t3
Ursa Operating Company LICAttachmeût 1Site Securify Inspection FormFacilÍty Name:Looation fiegal or lallong):Cunent Operations Phase (productlon, sales, other):Date of Inspection:Lease #:Inspeoted By:This inspection should be completed "as-needed" by qualified personnel. Any item marked "No" requires additional descriptionand/or reference to operations phase on Site Facilþ Diagram (Attachment A).T4
Ursa Operating Company LLCAttachment 1Section III.B - LACT Seals (if present on site)NotesSEAL NUMBERNoYesSee Attachment B for Meter DiagramSample probe closed and sealed?Sampler volume control closed and sealed?Valves on entry/exit lines closed and sealed?Temperature recorder closed and sealed?Back pressure valve closed and sealed?Drain valve(s) closed and sealed?Manual sampling valve(s) closed and sealed?Meter assembly (counter head, meter head,automatic temperature compensator) closed andsealed?Section III.D - Meter By-PassNotesN/ANoYesGas meters and/or LACT meters free of by-passpiping installations?Section III.H - Site SecurityNotesN/ANoYesSite Specific Security15
Ursa Operating Company LLCAttachment 1Additional Inspection Comments:In the case of any evidence of theft or mishandling (missing or broken seals, valves in incorrect positions, by-passes installed),report to Ursa Operating Company IMMEDIATELY after completing this inspection.Printed Name:Signature:16
Ursa Operating Company LLC Attachment I
7.0 Seal Tracking Requirements
To ensure compliance with Onshore Order 3, and to provide a document which tracks all
seal installations and removals, a seal tracking form has been provided within this Section.
The form shall be completed at the time of the oil loading operation by the Ursa personnel
providing oversight of the loading operation. A designated form for each field shall be
managed in accordance by the designated Ursa personnel in both hardcopy and electronic
form. The personnel managing the seal tracking form shall conduct the monthly site
inspections and cross reference the seal tracking form with the respective site inspection.
17
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Ursa Operating Company LLCAttachment 1SealFormNotilication to the AuthorizedOffrcer - (Yi'l\ and Date)Re¿son forRemovaVlnstallatlonInstalled SealNumberRemoved SealNumberDâte of SealInst¡llation/RemovalValve II)Tank IdNumberlæaseNumberFacility Name:18
Ursa Operating Company LLC8.0 Operator and Federal Contact InformationTable 5. Contact Information* Only notify the BLM field offlrce which the respective facility is found in.Attachment IUrsa Contact ListEmailsvau ghn(Eursare sources. comSameSameSamerbleil@,ursaresources.comtmall@ursaresources.comFederal Contact List*jjking@blm.qovOffice(970) 329-437rSameSameSame(970) 329-4373(970) 329-437s970-876-9000Mobile(970) 623-9s39SameSameSame(720) 42s-0303(970) 618-2lss970-876-9036Field ContactsShane VaughnSameSameSameRobert BleilTara MallJulie J. KingBattlement MesaCastle Springs/'Wolf CreekGravel TrendRoanÆ.{orth Gravel TrenchRegulatory and EnvironmentalHS&EColorado River Valley Field Office,2300 RiverFrontage Road, Silt, CO 81652l9
Ursa Operating Company LLC Attachment I
9.0 Removal of Oil Requirements
The removal of oil from a facility for sale or transport must be documented and observed
by specifred persons (i.e. gauger, IJrsa representative, BLM personnel). A form has been
provided in this Section to fulfill the documentation requirement.
Prior to removal of oil from tanks, a verbal notification to the respective BLM personnel
is required. The authorized offlrcer or representative from the BLM is to be present at the
time of loading. The BLM personnel may collect independent gauging measurements.
Their presence is to provide oversight during the gauging process to veriS' the volume of
oil being loading and documented is accurate for royalty purposes.
20
Ursa Operating Company LLC Attachment 1
Removal of Oil Form
Removal of Oil From Tanks be Means Other Than Through a LACT Unit
Date:
Name of seller:Ursa Operating Company, LLC
Federal or Indian lease number:
Legal location of the tank:
Tank number and capacity
Valve Number
Seal number prior to loading*:
Seal number after loading:
Opening gauge and temperature*
Closing gauge and temperature*
Observed gravity and sediment and water content*:
Name of Gauger:
Signature of Gauger:
Name of Ursa representative
Signature of Ursa representative:
Name of Federal representative:
Signature of Federal representative
* Omission of the designated information constitutes a major violation, complete missing
information and submit within 3 s of notice
2t
Ursa Operating Company LLC Attachment 1
L0.0 Theft or Mishandling of Oil Protocol
Internal Notifi cation Protoco I
Personnel identifying the incident will report all applicable information to the
Regulatory and Environmental Manger (REM) in addition to the Health and
Safety Manager (H&S).
In the event of criminal activity, law enforcement may be involved. The REM
andlor H&S will determine the involvement of law enforcement.
The form included in this section shall be completed within 10 days of
discovery of the incident.
o Any additional information not identified within the form is to be
attached.
o All forms shall be retained for a period of seven years in
accordance with the regulatory requirements.
10.1
a
o
a
10.2 FederalNotification Requirements:
. The theft of mishandling of oil shall be reported no later than the next business
day after discovery of the incident to the authorizing officer.
. All oral reports shall be followed up with a written report within l0 business
days.
o Please see the form within this Section for the written report form.
o Violations:
" t*i
l;?;iiliä"i,åïälürffiffi.ou"st, and submit report or
incident within 10 business days after notice of failure to file a
"'"'î ffi,ä"i]iffiî;* request and submit reporr or
incident within 10 business days after notice of failure to report
incident is received.
22
Theft or Mishandline of Oil
Verbal notification required: next business day after incident is discovered
Written notifÏcation required: 10 days after incident is discovered
Date:
Name of seller:Ursa Operating Company, LLC
Name of Ursa representative reporting the incident:
Name of the person who discovered the incident
and company:
Date and time the incident was discovered:
Federal or Indian lease number
Legal location of the tank:
Tank number and capacity:
Estimated volume oil or condensate removed:
The manner which access to the oil was removed
The way access was obtained:
Whether the incident was reported to local law
enforcement agencies and company security:
Signature of Ursa representative
Ursa Operating Company LLC Attachment I
Theft of Mishandling of Oil Form
23
Ursa Operating Company LLC Attachment I
11.0 Site Security Plan
The operator shall establish a site security plan for all facilities. The plan need not be submitted
to the authorized officer, but the authorized officer shall be notified of the location where the
plan is maintained and the normal working hours of said location. The plan shall be available to
the authorized officer upon request. The plan shall include, but is not limited to the following:
A self-inspection program that monitors production volumes and ensures
compliance with all seal requirements at each storage and sale facility and each
LACT unit, if applicable
o See form found in Section 6.0
A system to ensure the maintenance of accurate seal records and the completion of
accurate run tickets
o See forms found in Sections 7.0 and 8.0
A system to ensure the reporting of incidents of apparent theft or mishandling of
oil
o See form in Section 9.0
A system to ensure that there are no by-pass of meters
o See form in Section 6.0
A list of the leases, communitization agreements, unit agreements, and specific
facilities that are subject to each plan
o See Tables I and2 of this document.
Documentation that the authorized officer has been notified of the completion of a
plan and site facility diagram(s) and the leases, communication agreements, unit
agreements, and specific facilities that are subject to each plan and diagram(s)
Documentation that the authorized officer was notified within 60 days of
completion of construction of a new facility or of commencement of first
production or of inclusion of the production from a committed nonfederal well
into a federally supervised unit or communitization agreement, whichever occurs
first, whether that facility is covered by a specific existing plan or a new plan has
been prepared.
o See Form in Section I 1.0 of this document.
a
o
a
a
o
a
24
Ursa Operating Company LLC Attachment I
Notification to Authorized Representative Form
Ursa Representative Signature :Date
Supplemental information to be attached to this form as an attachment(s).
Name and Title of Ursa Representative Providing Notification:
Federal Field Ofhce Notification Provided to
of a Plan
Completion of a Site Diagram
Lease addition of change
Communication Agreement
Unit Agreement
Providing list of locations with are
subject to the Order
Date of construction completion
Date of commencement of first
production:
Date of inclusion of production from a
committed nonfederal well into a
federally supervised communitization
agreement:
Was this notification provided within 60 days of completion of construction, or of
commencement of first production, ¿r of inclusion of the production from a committed
nonfederal well into a federally supervised communitization agreement?
NoYes
If no, why:
25
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Application Status
Active
Active
Active
Active
Active
Active
Active
Active
Active
Active
ParcelNum
240935300L26
23933611801L
239s01230033
239320301038
2L2735200079
239308300006
239L20400784
2393294764OL
23930820sAL2
239308205013
General Description
New S/F Dwelling with finished basement and covered patios
New S/F Dwelling with attached garage and covered and uncovered patios and decks
New S/F Dwelling on crawl space with attached garage and covered patios and deck
New S/F dwelling on crawl space w/ covered & uncovered patios/ deck & attached garage
New S/f Dwelling on unfinished basement with attached garaged covered and uncovered patios and decks
New S/F on unfinished basement w/ covered & uncovered patios/decks
construction of a guest house from shipping containers
single family on partial unfinished basement & crawl space w/ covered/uncovered patio/deck & detached garage
new single family residence
s[ngle family on unfinished basement w/ covered patios & attached garage
Address
7817 CR 306
1-26 Ranch Creek Ln.
TBD River Bend Way
154 W. Diamond A Ranch Rd.
TBD CR 260
TBD Sec08, T07S, R88W
TBD CR 102
Sec29, T07S, R88W
TBD Sec07, T07S, R88W
Sec07, T07S, R88W