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FILED
BEFORE THE BOARD OF OIL, GAS AND MININGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FOR AGENCYACTION OF FIDELITY EXPLORATION &,PRODUCTION COMPANY FOR AN ORDERAUTHORIZING THE FLARING OF GAS IN EXCESS OF
THE AMOUNTS ALLOWED LINDER UTAH ADMIN.coDE RULE R649-3-20(1.1) FROM THE CANE CREEKL'NIT 32-I-25-19 WELL LOCATED IN SECTION 32,
TOWNSHIP 25 SOUTH, RANGE 19 EAST, SLM,GRAND COUNTY, UTAH
REQUEST FOR AGENCY ACTION
Docket No. 2015-01I
Cause No. 196-45
COMES NOW, Fidelity Exploration & Production Company ("Fidelity"), acting by
and through its attorneys, MacDonald & Miller Mineral Legal Services, PLLC, and
pursuant to Utah Code Ann. $40-6-5(3XÐ and Utah Admin. Code Rule R649-3-20(5), and
hereby respectfully requests the Board of Oil, Gas and Mining (the "Board") to enter an
order authorizing Fidelity or its successors, as operator of the Cane Creek lJnit32-l-25-19
Well (the "'Well"), located within Section 32, Township 25 South, Range 19 East, SLM,
Grand County, Utah, to flare gas produced from said well in an amount not to exceed
100 MCFPD, commencing on April 1,2015 and until such time as additional drilling and
production from nearby wells and economics justiff construction of a gathering line to
collect the gas and transport it to Fidelity's Dead Horse Lateral Pipeline and Processing
Plant for sale.
In support of this request, Fidelity respectfully states and represents:
l. Fidelity is a Delaware corporation in good standing with its principal place
of business in Denver, Colorado. It is an indirect subsidiary of MDU Resources Group,
Inc. Fidelity is duly qualified to conduct business in the State of Utah, and is fully and
appropriately bonded with all relevant Federal and State of Utah agencies.
2. The oil and gas underlying subject Section 32 are owned by the State of Utah
and are administered by the Utah School and Institutional Trust Lands Administration
("TLA"). They are cuffently subject to State of Utah Oil, Gas and Hydrocarbon Lease
\{tr--43565 under which Fidelity is the sole lessee and operating rights owner. The Lease
and the oil and gas subject thereto are deemed fully committed to the Cane Creek Federal
Exploratory Unit (the "Unit"), administered by the Bureau of Land Management ("BLM").
3. Pursuant to the terms of the governing Unit and Unit Operating Agreements
and to a duly approved application for permit to drill ("APD"), Fidelity spud the Well on
February 12,2014 from a surface hole location 858 feet FWL and 1,114 feet FSL in the
SW%SW% of Section 32, and drilled it horizontally with intersection with the productive
Cane Creek formation at 1,576 feet FWL and 1,539 feet FSL in the NW%SW% of Section
32 and a terminus located 861 feet FNL and 897 feet FEL in the NE7¿NE% of Section32.
The Well was completed as a producing oil well on May 2,2014, with hrst production on
May 5, 2014.Initial production rates were 181 BOPD and 182 MCFPD; however, those
rates dropped off significantly.
2
4. Pursuant to a duly approved Sundry Notice, the Well was stimulated on
November 19, 2014, resulting in increased average production rates of 420 BOPD and
239 MCFPD. A "IJnit paying quantities" well determination from the BLM is pending
which will determine if a Unit participating area will be established or whether production
will be allocated on a leasehold basis only.
5. The Well is located on remote lands, far away from any residence, and more
than three (3) miles from the closest well with a gathering line connecting to the Dead
Horse Lateral Pipeline.
6. Because the Well is within the Unit, under the Board's Orders entered in
Cause No. 196-44,the last ofwhich was entered December 18,2014, Fidelity is authorized
to flare gas from the Well provided the aggregate amount flared from the Unit does not
exceed 4,000 MCFPD and the amount flared from the Well does not exceed 775 MCFPD.
However, those orders are currently scheduled to expire on March 31,2015.
7 . As required under the provisions of Utah Admin. Code Rule R649 -3-20(5),
Fidelity addresses the criteria for submitting and granting this Request as follows:
a) Subsection 5.1 - Statement Justifying the Need to vent or Flare MoreThan the Allowable Amount. While the Dead Horse Laterul Pipeline andthe Processing Plant will be functional and first phase construction of theUnit gathering system will be complete by March 31,2015, the gatheringline to the Well is not included in the first phase construction, the Well beingfurther west of the existing Unit participating area. Furthermore, while theproduction rates from the Well after stimulation are encouraging, additionaldrilling and similar production results are required before second phase
3
gathering line construction becomes feasible. Currently, the Well producesan average 83 MCFPD, only 23 MCFPD over the regulatory limit. Based oncurrent data analysis, Fidelity believes the actual decline curve should putgas production from the V/ell below the 60 MCFPD limitation by May 31't,2015. The Well is currently flowing naturally and choking back itsproduction may lead to plugging issues and damage to the reservoir,permanently compromising the encouraging production achieved afterstimulation.
b) Subsection 5.2 - Description of Production Test Results. Production testswere run in accordance with the Division and BLM administrative approvals.Prior to stimulation, the Well produced at roughly 57 BOPD with an averageGOR of 620 scf/bbl. After stimulation, the Well is averaging 140 BOPD withan average GOR of 570 scf/bbl. Average gas production is 83 MCFPD. Thedaily average gas production rate of the Well will therefore exceed theapproximately 60 MCFPD regulatory flaring limitation once the existingBoard Orders expire.
c) Subsection 5.3 - Chemical Analysis of Produced Gas. The chemicalanalysis from the Well is attached as Exhibit "l" hereto and by this referenceincorporated herein.
Subsection 5.4 - Estimated Oil and Gas Reserves. Given the limited testdata and complex nature of the formations, it is premature to provide anaccurate estimate of reserves. However, based upon the minimal testingperformed to date, economic recoverable oil could be 56.3 MBO and gasreserves could be 31.53 MMCF for the Well. Updated information andreserves estimate will be presented at the hearing.
e) Subsection 5.5 - Descriptions of Reinjection or Other Conservation-Oriented Alternatives. Given the large capital commitment made byFidelity in construction of the Dead Horse Laterul Pipeline and ProcessingPlant, a gathering line from the Well is the only practical and economicalternative to flaring. No other alternative, given the rate of gas productionfrom this one well, is viable. However, the rate of gas production from thisone well also does not economically justiff commencement of the secondphase gathering construction. Additional drilling and similar productionresults are required before such an undertaking makes economic sense,
4
d)
particularly given the current oil price decline. Weighing these factorsagainst the relatively small amount of gas to be flared supports the requestedauthorization.
Subsection 5.6 - Description of the Amount of Gas Used in LeaseOperations. None at this time.
Subsection 5.7 Economic Evaluation Supporting Operator'sDetermination that Conservation of Gas is Not Economically Viable. See(a) and (e) above. A more detailed economic analysis of alternatives will besupplied as an exhibit and elaborated upon at the hearing.
h) Subsection 5.8 - Any Other Information Pertinent to a Determination ofWhether Marketing or Otherwise Conserving the Produced Gas IsEconomically Feasible. None.
8. Fidelity will take all steps required under State and Federal regulation for the
protection of the health, safety and welfare of the general public.
9. Fidelity believes and therefore alleges that granting its Request will be in
furtherance of the public policies of this State to promote greater recovery of oil without
waste and with protection of the correlative rights of all affected owners, and is just and
reasonable under the circumstances.
10. Fidelity will, in accordance with Board rules, timely submit exhibits and
present testimony in support of these allegations.
I 1. Fidelity will separately hle a certif,rcate of mailing listing all parties known
to it, based on a search of the respective TLA and Grand County realty records and the
Ð
s)
5
records ofthe Division, whose "legally protected interests" will be affected by this request.
There are no respondents or adverse parties known at this time to Fidelity.
WHEREFORE, Fidelity respectfully requests :
l. That this matter be set for hearing on March 25,2015;
2. That notice of such hearing be given as provided by law; and
3. That, upon sufhcient evidence produced and testimony given at the hearing,
the Board grant this Request and issue an order:
a) Authorizing Fidelity or its successor(s) as Operator of the Cane Creek Unit32-l-25-19 well to flare gas produced from said Well in an amount not toexceed 100 MCFPD commencing on April 1,2015 and until such time asadditional drilling and production from nearby wells and economics justiffconstruction of a gathering line to collect the gas and transport it to Fidelity'sDead Horse Lateral Pipeline and Processing Plant;
b) Making such findings and orders in connection with this Request as it deemsnecessary; and
c) Providing for such other and further relief as may be just and equitable underthe circumstances.
6
Respectfully subrnitted this lOtr' of Febrvary, 2015.
M¡.cDONALD & MILLER MINERALLEGAL SERVICES, PLLC
;")
M
7090 S. Union Park Ave., Ste. 400Midvale, Utah84047Telephone: (801) 676-0050Facsimile: (801) 676-0051E-Mail: [email protected]
Attorneys for Petitioner Fidelity Exploration& Production Company
Petitioner's Address
Fidelity Exploration & Production CompanyAttention: Wes Adams, Landman1801 California Sr., Suite 2500Denver, CO 80202Telephone : 720-9 I7 -3006Facsimile: 303-893-1964E-Mail : [email protected]
FMM:mhk1050.06
7
EXHIBIT 1
ACT ANaryrrYSTEMS INC.
PROJECTNO. :
COMPANY NAMEACCOUNTNO. :
PRODUCER :
LEASE NO. :
NAME/DESCRIP:
-..FIELD DATA"-SAMPLE PRES. :
VAPOR PRES, :
COMMENTS :
COMPONENT
201407',t54FIDELITY EXPLORATION
365 S. MAIN STBRIGHTON, CO
8060 r
303-637-01 50
EXTENDED NATURAL GAS ANALYSIS ('DHAI
MAIN PAGE
ANALYSIS NO. :
ANALYSIS DATE:SAMPLE DATE :
CYLINDER NO. :
SAMPLED BY :
PRODUCED TREATER GAS 10:20CANE CREEK UNIT 32-1-25-19
SAMPLE EMP,: 12135 AMBIENT TEMP.:
GRAVITY :
SPOT; No PROBE; LENGTH oF H2S STATN @ OppM (1-7ppM) 10:2s
03AUGUST 1, 2014JULY 28,20141373GALE MCENDREE. EMPACT
ALCOHOLSHELIUMHYDROGENOXYGEN/ARGONNITROGENCARBON DIOXIDEMETHANEETHANEPROPANEI-BUTANEN-BUTANEI-PENTANEN-PENTANE
MOLE %0.0009
0.020.000.010.940.01
56.5142019.460913.7729
1.65014.40650.88431.15171.1785
100.00000
MASS %
o.0024
GPM @14.650
5.20633.79620.54061.39010.32090.4172o.4821
12.1534
14,6501463.3 /scf1437.7 ßcr1602.7 lscr1574.7 ßcr
20334.9 nb22276.9 ilb
GPM @14.730
0.000.000.010.960.02
33.'1627021.404822.2152
3.50829.36842.33083.03953.9780
1 00.00000
5.23473.81690,54351.3977o.32270.41950.4846
12.2196
14.730-Elsct1445.7 ßcr161 1 .5 /sct1583,4 /sct
20445.9 ilb22398.5 ilb
HEXANES PLUSTOTALS
BTDXCOMPONtrNTS MOLE% WTVOBENZENE O,O2B7 O.O82O
TOLUENE 0.0185 0,0624ETHYLBENZENE O.OO15 O.OO58XYLENES 0.0058 0.0226TOTALBre
B'I'U@LOW NET DRYREAL:
NET WET REAL :
}IICH GROSS DRY REALGROSS WET REAL
NET DRY REAL:GROSS DRY REAL
RELATIVE DENSITY (AlR=1 ):(CÁLC: GPA srD 2t45 &rP-tt @t4 6e6 & 60 F) COMPRESSIBILITY FACTOR :
'(DET¿llLED Itl'DROCARITON INAL!'S4SNJ I99J) : ÁSilt Dó710T}IIS DAT¿I TLIS ßEEN /|CQUIRED TI!ROUGII APPLICATION OF CURRENT STATE-OF-| IE-ART ANÅLI.IICAL TEcIIN]QUES.TIIEUSEOFTIIISINFOR'\IATIONISTIIERESPONSIBLITI'OFTIIEUSER EAIPACTIN!ILI'\7CÅ¿SI'SruIlJì/SSUN/¿:SNORESPONSIBLITT FOR )CCUR.ICt'oF TItE REPORTDD tNFOR,lt..tTtON NOR /lNt'CONSEQUE^,CES oF tt,S ÅppLICATtON.
0.94270.99394
HXHIBI L
ACT ANlrrrrrYSTE,MS INC.
stf2È
PROJECTNO. :
COMPANY NAMEACCOUNTNO.:PRODUCER :
LEASE NO. :
NAME/DESCRIP:
*,*FIELD DATA***SAMPLE PRES.:VAPOR PRES, :
COMMENTS :
Componet
201407154FIDELITY EXPLORATION
365 S. MA.IN ST.BRTGHTON, CO
80601
303-637'01 50
EXTENDED NATURAL GAS ANALYSIS TDHA)
GLYCALC INFORMATION
ANALYSIS NO.:ANALYSIS DATESAMPLE DATE :
CYLINDER NO. :
SAMPLED BY :
PRODUCED TREATER GAS'10:20CANE CREEK UNIT 32-1-25.19
SAMPLETEMP.: 121
35 AMBIENT TEMP.:GRAVITY
SPOT; NO PROBE; LENGTH OF H2S STAIN @ OPPM (1-7PPM) 10:25
03AUGUST 1,2014JULY 28,2014't373GALE MCENDREE - EMPACT
HeliumHydrogenCarbon DioxldeNitrogenMethaneEthanePropanelsobutanen-Butanelsopentanen-PentaneCyclopentanen-HexaneCyclohexaneOther HexanesHeptanesMethycyclohexane2,2,4 T rimelhyl pentan eBenzeneTolueneEthylbenzeneXylenesC8+ Heavies
Mole %0.020.000.01
0.9456.51420
19.4609'13.7729't.6501
4.40650.84361,15170.04070.30660.08060.37560.1 9480.04620.00050.02870.01850.00150.00580.1197
EBg1o0,01
0.0009
wt%0.000.00o.o20.96
33.162702',1.4048
22.21523.50829.36842.22643.0395oj0440.96640.24811.1787o.71180.16590.002'l0.0820o.06240.00580.0226o.5322
s9.e876õ'0.01
0.0024
SnblolalOxygen/ArgonAlcohols
1 00.00000 't00.00000
THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT
STATE-OF-THE ART ANALWCAL TECHNIQUES. THE APPLICATIONS OF THIS 'NFO
RMATION IS THE
RESPONS/B/LIry OF THE USER. EMPACT ANALYTICAT SYSTEMS, 'NC.
ASSUMES NO RESPONS'8'I'ryFOR AÇCURACY OF THE REPORTED INFORMATION NOR A/VY CONSEQUENCES OF ITS APPLICATION.
PROJECTNO.:COMPANYNAMEACCOUNTNO. :
PRODUCER :
LEASENO. I
NAMEiDESCRIP:
***FIELD DATA*+{SAMPLE PRES. :
VAPOR PRES. :
COMMENTS :
COMPONENT
EMPACT
0.00
0.00
0.01
0.96
o.o2
33.16270
21.4048
22.2152
3.5082
9.3680
0,0214
2.20s0
0,0002
0.0004
3.0376
0.0016
0.0 t 86
0,1044
0.0694
0.5800
0.0006
0.2931
0,00t 9
0.9664
0.0007
0.2170
0,020s
0.00 t 5
0.0820
0.0022
0.2481
0.10t90.0359
0.0198
0.ll140.024t0,02 ts0.0048
0.034 r
0,0021
0.0006
OXTENDßD NATURÁ.L GAS ANALYSIS (*DHA)
DHA COMPONENT LIST
201407154 ANALYSIS NO. : 03
FIDELITY EXPLORATION ANALYSÍS DATE: AUGUST l,2014SAMPLE DATE : JULY 28,2014CYLINDER NO. : 1373SAMPLEDBY : GALEMCENDREE-EMPACT
PRODUCED TREATER GAS l0:20CANE CREEK UNIT 32- t -25- I9
SAMPLE TEMP. : l2l35 AMBIENT TEMP.:
GRAVITY :
SPOT; NO PROBE; LENGTH oF Fr2S STAIN @ 0PPM (l-7PPM) l0:2s
GPM @I 4.650
GPM @14.730PIANO # MOLEY" MASS %
0.02
0.00
0.0 t
0.94
0,01
s6.st420t9.4609
t3.7729
1.6s0l
4.4063
0.0081
0.8355
0.0001
0.0002
t.1510
0,0006
0.0059
0.0407
0.0220
0, | 840
0.0002
0.0930
0.0007
0.3066
0.0002
0.0705
0.00s6
0.0004
0.0287
0.0006
0.0806
0.0278
0.0098
0.0055
0.0304
0.0067
0.0060
0.0013
0.0095
0.0005
0.0002
Page 1
365 S. Main Street, Brighton, CO 80601
Heliunr
Hydrogen
Oxygen/Argon
Nitrogen
Carbon Dioxide
Methane
Ethane
Propane
i-Butane
n-Butane
2,2-Dinrethylpropone
i-Penlane
i-Propanol
UnknorvnC4s
n-Pentane
t-Butanol
2,2-D irnethy lbula ne
Cyclopentane
2,3-Dirnetlrylbulane
2-Methylpentane
i-Br¡tanol
3-Methylpentane
UnknorvnC5s
n-Hexane
2,2-Dinrethylpentane
Methylcyclopentane
2,4-Dirnethylpenlane
2,2,3-Trinrethylbutane
Benzene
3,3-Dirnethylpentane
Cyclohexane
2-Methylhexane
2,3-Dirnethylpenlane
I, I -Dinrethylcyclopentane
3-Methylhexane
I c,3-Dintethylcyclo¡rentane
I t,3-Dirnethylcyclopenlane
3-Ethylpentane
I 1,2-Dinrethylcyclopentane
2,2,4-Tri nrelhylpentane
UnknorvnC6s
PI
P2
P3
t4
P4
I5
I5
X3
U4
P5
X4t6
N5
T6
16
x4I6
U5
P6
t7
N6
l7t7
A6
t7
N6t7
t7
N7t'tN7
N7
t7
N7
t8
U6
5.206
3.796
0.s41
1.390
0.003
0.306
0.000
0.000
0.417
0.000
0.002
0.ot20.009
0.076
0,000
0.038
0.000
o.126
0.000
0.025
0.003
0.000
0.008
0.000
0.027
0.0r3
0.004
0.002
0.01 4
0.003
0.003
0.001
0.004
0.000
0.000
s.235
3.817
0.s44
t.398
0.003
0.308
0.000
0.000
0.420
0.000
0.002
0.01 2
0.009
0.077
0.000
0.038
0.000
0.t270.000
o.025
0.003
0.000
0.008
0.000
0.027
0.013
0.004
0.002
0.014
0.003
0.003
0.00 t
0.004
0.000
0.000
EMPACT Analylical Systems, lnc 303-637-01 50
n-Heptane
I c,2-Dimethylcyclopentane
Methylcyclohexane
2,2-Dirnethylhexane
Ethylcyclopentane
2,5-Dinrethylhexane
2,2,3 -Trimethylpentane
2,4-Dimethylhexane
I c,2t,4-Trimethylcyclopentane3,3-Dinrethylhexane
I t,2c,4-Trimethylcyclopentane
2,3,4-Trimethylpentane
Toluene
2,3-Dimethylhexane
2-Methyl-3-ethylpentane
l, 1,2-Trimethylcyclopentane
2-Methylheptane
4-Methylheptane
3-Methyl-3-elhylpentane
3,4-Dímethylhexane
I c,2c,4-Tri methylcyclopentane
I c,3-Di methylcyclohexane
3-Methylheptane
I c,2t,3-Trirlethylcyclopentane
3-Ethylhexane
I t,4-Dimethylcyclohexane
l, l-Dirnethylcyclohexane
3 c-Ethylmethylcyclopentane
3 t-Ethylmethylcyclopen lane
2 t-Ethylnrethylcyclopentane
I, I -Methylethylcyclopenlane
2,2,4-Trimethylhexane
I t,2-Dimethylcyc lohexane
UnknownCTs
n-Octane
I c,4-Dimethylcyclohexane
i-Propylcyclopentane2,4,4-Trimethylhexane
2,3,5-Trimethylhexane
2,2,3,4 -T efi amelhylp en tan e
2,3,4-Tri methylhexane
I c,2-Dimethylcyclohexane
l, 1,4-Trimethylcyclohexane
2,2,3 -Trimethylhexa ne
2,4-Dimethylheptane
4,4-Dimethylheptane
Ethylcyclohexane
n-Propylcyclopentane
I c,3c,5-Trimelhylcyclolrexane
2,5-Dirnethylheptane
3,3-Diurethylheptane
3,5-Dimethylheptane
l, 1,3-Trimethylcyclohexane
Ethylbenzene
I c,2 t,4t-Trinrethylcyclohexane
2,3-Dinrethylheptane
I,3-Dimethylbenzene (nr-Xylene)
1,4-Dimethylbenzene (p-Xylene)
3,4-Dimethylheplane
3,4-Dirnethylheptane (2)
4-Ethylheptane
4-Methyloctane
2-Methyloctane
3-Ethylheptane
Page 2
365 S. Main Skeet, Brighton, CO 80601
P7
N7
N7I8
N7
I8
I8
I8
N8
I8
N8
I8
^7I8I8
N8
l8
I8
I8
I8
N8
N8
I8
N8I8
N8
N8
N8
N8
N8
N8
I9
N8
U7
P8
N8
I8
t9
t9
19
19
N8
N9
I9
T9
t9
N8
N8
N9
I9
T9
19
N9
I8
N9
T9
A8
A8
t9
t9
I9
I9
l9
t9
0.0880
0.0008
0.0462
0.0029
0.0016
0.0010
0.0006
0.0024
0.00r 8
0.0007
0,0014
0.0001
0.0185
0.00 t 9
0.0007
0.0001
0.01l90.0026
0.0005
0.0007
0.0001
0.0001
0.0055
0.006t
0.001I
0.0024
0.0008
0.0001
0.0003
0.0002
0.000s
0.0001
0.0023
0.0006
0.0208
0.0036
0.0001
0.000r
0.0001
0.000t0.0002
0,0006
0.0033
0.00t 9
0.000r
0.0001
0.0017
0.0012
0.0002
0.0001
0,0001
0.0001
0.000r
0.0015
0.0006
0.0003
0.0029
0.00 r 4
0.0002
0.0002
0.0002
0.0009
0.0014
0.0003
0.3226
0.0029
0. l 659
0.0121
0.0057
0.00420.0025
0.01 00
0.00740.0029
0.0057
0.0004
0.0624
0.0079
0.0029
0.0004
0.0497
0.0109
0.0021
0.0029
0.0004
0.0004
0.0230
0.0250
0.0046
0.0098
0.0033
0.0004
0.0012
0.0008
0.0021
0.000s
0.0094
0.0022
0.0869
0,0148
0.0004
0.0005
0.0005
0.0005
0.0010
0.0025
0.0153
0.0089
0.0005
0.0005
0.0070
0.0049
0.0009
0.000s
0,0005
0,0005
0.000s
0.0058
0.0028
0.0014
0.0r l30,00ss
0.0010
0.001 0
0.0010
0.0042
0.0066
0.00 t4
0.040
0.000
0.019
0.001
0.001
0.001
0.000
0.001
0.00t0.000
0.001
0.000
0.006
0.001
0.000
0.000
0.006
0.001
0.000
0.000
0.000
0.000
0.003
0.003
0.001
0.001
0,000
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.01 t0.002
0.000
0.000
0.000
0.000
0.000
0.000
0.002
0.001
0.000
0.000
0.001
0,001
0.000
0.000
0.000
0.000
0,000
0.001
0.000
0.000
0.001
0.001
0.000
0.000
0.000
0,001
0.001
0.000
0.040
0.000
0.019
0.001
0.001
0.001
0.000
0.001
0.001
0.000
0.00 t0.000
0.0060.001
0.000
0.000
0.006
0.001
0.000
0.000
0,000
0.000
0.003
0.003
0.00 r
0.001
0.000
0.000
0.000
0.000
0.000
0.000
0.00r
0.000
0.01 I0.002
0.000
0.000
0.000
0.000
0.000
0.000
0,002
0.00 t
0,000
0.000
0.001
0.001
0.000
0.000
0.000
0.000
0.000
0.00t
0.000
0.000
0.001
0.00t
0.000
0.000
0.000
0.00 t
0.00 r
0.000
EMPACT Analytical Systems, lnc 303-637-01 50
3-Methyloctane
I c,2t,4c-Trimethylcyclohexane
I, 1,2-Trimethylcyclohexane
3,3-Diethylpentane
1,2-Dimethylbenzene (o-Xylene)
i-Butylcyclopentane
Unk¡orvnCSsn-Nonane
l, l -Methylethylcyclohexanei-Propylbenzene
i-Propylcyclohexane
2,2-Dirnethyloctane
2,4-Dinethyloctane
2,5-Dimethyloctane
n-Butylcyclopentane
3,3-Dirnethyloctane
n-Propylbenzene
3,6-Diurethyloctane
3-Mef hyl-5 -elhylheptane
1,3-Methylethylbenzene
1,4-Methylethylbenzene
1,3,5-Trinethylbenzene
2,3-Dirnethyloctane
5-Methylnonane
1,2-Methylethylbenzene
3-Ethyloctane
3-Methylnonane
t-Butylbenzene
i-Butylcyclohexane
i-Butylbenzene
UrrknorvnC9s
n-Decane
1,2,3 -Trimethylbenzene
1,3 -Methyl-i-propylbenzene
Sec-Butylcyclohexane
1,2-Methyl-i-propylbenzene
1,3-Diethylbenzene
1,3 -Methyl-n-propylbenzene
I ,4-Díethylbenzene1,3-Dimethyl-5-ethylbenzene
I ,2-Diethylbenzenet-Decahydronaph thalene
1,2-Methyl-n-propylbenzene
1,4-Dimethyl-2-ethylbenzene
1,2-Dirnethyl-4-ethylbenzene
1,3-Dimethyl-2-elhylbenzene
1,2-Dimethyl-3-ethylbenzene
1,4-Methyl-t-butylbenzene
UnknorvnCl0s
n-Undecane
1,4-Ethyl-i-plopylbenzene
1,2,4,5-Tetrarnethylbenzene
1,2-Methyl-n-butylbenzene
1,2,3,5-Tetramethylbenzene
1,2-Methyl-t-buglbenzene
1,2-Ethyl-n-propylbenzene
1,3-Methyl-n-butylbenzene
1,3-Di-i-propylbenzene
sec-Pentylbenzene
n-Pentylbenzene
1,4-Di-i-propylbenzene
Naphlhalene
UnknorvnCl lsn-Dodecane
Page 3
365 S. Main Skeet, Br¡ghton, CO 80601
I9
t9
N9
I9
A8
N9
U8
P9
N9
A9
N9
n0It0Il0N9
Il0A9
il0ì10
A9
A9
A9
n0il0A9
il0Il0Al0Nl0Al0U9
Pl0A9
Al0Al0At0A.10
Al0Al0At0410A9
Al0Al0Al0Al0Al0Allut0PlrAllAllAllAllAllAllAllAllAllA1 I
AllAt0ullP12
0.0016
0.000t
0.0001
0.000r0.0015
0.0007
0.00020.0067
0.0004
0.0003
0.0002
0.000 t0.0002
0.0001
0.0008
0.0002
0.0008
0.0003
0.0004
0.0004
0.000t
0.0004
0.0001
0.0004
0.0005
0.0001
0.0004
0.0010
0.0002
0,0001
0.0021
0.0027
0.0003
0.000r
0.0003
0.0002
0.0001
0.0001
0.0002
0.0001
0.0001
0.0001
0.0001
0.0001
0.0002
0.0001
0.0001
0.0001
0,0020
0.00r 3
0.0001
0.0001
0.0001
0.0001
0.0001
0.000t
0.0001
0.0001
0.0001
0.0001
0.000r
0.0001
0.0009
0.0006
0.0075
0.0005
0.0005
0.0005
0.0058
0.0032
0.0008
0.0314
0.00 t 8
0.00r3
0.0009
0.0005
0.0010
0.0005
0.0037
0.0010
0.0035
0.0016
0.0021
0.00t 80.0004
0,0018
0,0005
0.002t
0.0022
0.0005
0.0021
0.0049
0.0010
0.0005
0.0098
0.0141
0.0013
0.0005
0.0015
0.0010
0.0005
0.0005
0.0010
0.0005
0.0005
0.0006
0.0005
0.0005
0.00 t 0
0.0005
0.0005
0.0006
0.0104
0.0074
0.0006
0.0005
0.0006
0.0005
0.0006
0.0006
0.0006
0.0006
0.0006
0.0006
0.0006
0.0005
0.0052
0.0037
0.00 t
0.000
0.000
0.000
0.001
0.000
0.000
0.004
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.001
0.002
0.000
0.000
0.000
0.000
0.000
0,000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.001
0.001
0.000
0,000
0,000
0.000
0.000
0.000
0.000
0.000
0.000
0,000
0.000
0.000
0.00 t
0.000
0.00 t
0.000
0.0000.000
0.00 t
0.000
0.000
0.004
0.000
0.000
0,000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.001
0,002
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0,000
0.001
0.001
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0,000
0.000
0.000
0.001
0,000
EMPACT Analytical Systems, lnc 303-637-01 50
1,2,4-Trietlrylbenzene
1,2,3,4,5-Pentamethylbenzene
UnknorvnCl2s
n-Tridecane
Unk¡orvnCl3sn-Tetradecane
UnknorvnCl4sn-Pentadecane
UnknolnCl5sTOTAL
BTEX COìI{PONENTSBENZENETOLUENEETHYLBENZENEXYLENES
MOLE% WT%0.0287 0.08200.0185 0.06240.0015 0.00580.0058 0.0226
Bru @LO1V NET DRY REAL:
NET WET REAL :
HIGHGROSS DRYREALGROSS WET REAL
NET DRY REAL:GROSS DRYREAL
Al2413
ut2Pl3ul3Pt4ut4Pl5ul5
0.0001
0.000t
0.0007
0.0003
0.0004
0.0001
0.0002
0.000 t
0.0001
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.0000.000
0.000
0.000
0.000
0.000
0.000
0.000
100.00000
0.0006
0.0006
0,0040
0.0020
0.0027
0.0007
0.00 t 5
0.0008
0.0008
I 00J0000 12.1534
14.6501463.3
t2.2t96
I 4.730Æ
TOTAL BTEX 0.0s45 0.1728
RELATIVE DENSITY (AlR=1 ):(c/4Lc: cPA srD 2t4s &rP-t7 @t4.6e6 8¿60 F) COMPRESSIBILITY FACTORI(DEîAILED HI'DROCAABON ANALÍSISNJ 1993) ; ASTit D6730
TIIIS DATA IT.4S BEEN ACQUIRED THROUGH APPUCÅTION OFCURRENTSTATE.OF.TilE-¿IRTANALI'TIC¿ILTECHNIQUES.
TI]EUSEOI¡T¡I]SINFOR'IUTIONISTHERESPONSIIJLM'OFTHEUSER, EAIPACTÅNÁL''frcÅ¿STSTË,I/S,/SSU¡'ESNO
RESPONSIBLITr FORACCUR'|C\'OFTHE REPORTED INFOR|LIIION NOR ANI'CONSEOUENCES OIt ITS ¿tPPUCÅT|ON.
Page 4
365 S, Main Streel, Brighlon, CO 8060'1
/scI1437.7 lscÍ1602.7 /scf1574.7 ßcf
20334.9 /tb22276.9 rb
/scf1445.7 /scf161 1.5 /scf1 583.4 /scf
20445.9 nb22398.5 fib
0.94270.99394
EMPACT Analytical Systems, lnc 303-637-01 50
ACT AxarYSTE,MS
303-637-0150
EXTENDED NATURAL GAS ANALYSIS TDHAI
MAIN PAGE
365 S. MAIN ST.BRIGFITON, CO
80601
ANALYSIS NO. :
ANALYSIS DATESAMPLE DATE :
CYLINDER NO. :
SAMPLED BY :
SAMPLE TEMP. :
AMBIENT TEMP,:GRAVITY
"
MOLE% MASS %0.0039 0.0060
04AUGUST 3, 2014JULY 28,20140320GALE MCENDREE - EMPACT
80
GPM @ GPM @14.650 't4.730
PROJECTNO. :
COMPANY NAMEACCOUNTNO. :
PRODUCER :
LEASE NO, :
NAME/DESCRIP:
*-FIELD DATA-"SAMPLE PRES. :
VAPORPRES.:COMMENTS :
COMPONENT
TOTALS
BTEX COùIPONENTSBENZENETOLUENEETHYLBENZENEXYLENES
201407154FIDELITY EXPLORATION
PRE COMBUSTOR TANK GAS l0:35CANE CREEK UNIT 32-1-25.19
>1#
SPOT; NO PROBE
ALCOHOLSHELIUMHYDROGENOXYGEN/ARGONNITROGENCARBON DIOXIDEMETHANEETHANEPROPANEI-BUTANEN-BUTANEI-PENTANEN-PENTANEHEXANES PLUS
4.23955.50571 .0'1492.8970o.77771.03701.2755
16.7473
0.000.016.33
23.440.04
14.1037015.8'14619.93773,09419.16792.13912.85503.0640
1 00.00000
0.000.005.33
17.290.05
5.9567012.5',17423.14234.7338
14.02644.05765.42217.4677
100.00000
4.26275.53571.02052.91290.78211.04271.2826
16,8392
14.7301557.3 Acf1530.2 /scf1693.9 /sct1664.4 /sct
15580.4 /rb16943.8 nb
MOLE% IVT%o.0771 0.15850.0486 0.1 1790.0049 0.01370.0179 0.0500
BTU @LOW NET DRYREAL:
NET WET REAL :
HIGH GROSS DRYREALGROSS WET REAL
NET DRY REAL:GROSS DRY REAL
14.6501548.8 /scf1521.7 lsct1684.7 /scf1655,2 /scf
15495.8 nb16851 .7 nb
TOTAL BTEX 0.1485 0.3401
RELATIVE DENSITY (AlR=1 ):(cALC: GPÅ sfD 2t4s &rP-t7 @t4.6s6 & 60 F) COMPRESSIBILITY FACTOR :
.(DETAILED HI'DROCARDON ANALYSISNJ 1993) : ASTII D6730
THIS DATA I]ÅS BEEN ,ICSUIRED TIIROUGH APPLICATION OF CURRENT STATE.OF-THE-ART ANAL''ilCÅL TECHN|QUES,
THE USE OF TT'IIS INFORÀT¡TTION IS TITE RESPONSIBLITY OF T}IE USER. EÀIPACT ÁNÅLI'TICÅL SYSTEAIS, ASSUNl¿,SIVO
RESPONSIBLITI' FOR ÅCCURÁCI'OF TIIE REPORTED INFORI'I¿ITION NOR ÁNY CONSEQUENCES OF IT'S APPLICAîION.
1.31070.99204
ACT ANAI-YSTEMS INC.
365 S. MAIN ST.BRIGHTON, CO
80601
303-637-0'150
EXTENDED NATURAL GAS ANALYSIS (-DHAì
GLYCALC INFORMATION
PROJECTNO. :
COMPANY NAMEACCOUNTNO.:PRODUCER :
LEASE NO. :
NAME/DESCRIP:
**.FIELD DATA***SAMPLE PRES.:VAPORPRES,:COMMENTS :
Comoonet
201407't54FIDELITY EXPLORATION
PRE COMBUSTOR TANK GAS 10:35CANE CREEK UNIT 32-1-25-,I9
>1#
SPOT; NO PROBE
Mole o/o
ANALYSIS NO. :
ANALYSIS DATE:SAMPLE DATE :
CYLINDER NO. :
SAMPLED BY :
SAMPLE TEMP. :
AMBIENT TEMP.:GRAVITY :
o4AUGUST 3,20'14JULY 28,20140320GALE MCENDREE - EMPACT
80
HeliumHydrogenGarbon DioxideNitrogenMethaneElhanePropanelsobutanen-Butanelsopentanen-PentaneCyclopentanen-HexaneCyclohexaneOther HexanesHeptanesMethycyclohexane2,2,4 T rimelhylpentaneBenzeneTolueneEthylbenzeneXylenesC8+ Heavies
0.000.010.04
23.4414.10370
15.814619.93773.09419.16792.04512.85500.09400.77940.20120.97260.50150.11870.00030.07710,04860.00490.01790.3418
13"6õ6106.33
0,0039
100.00000
wt%0.000.000,05
17.295.9567012.517423.14234.7338
14.02643.88405.42210.17361.76800.44572,1 9681 .31850.30680.00090.15850.11790,01370,05001.0909
T.664-oo'5.33
0.0060
100.00000
St,btotal
Oxygen/ArgonAlcoholsTotal
THE DATA PRESENTED HEREIN HAS BEENÁCQUIRED THROUGH JUDICTOUS APPLICATION OF CURRENT
STATE-OF-THE ART ANALWICAL TFCHNIQUES. THE APPLICATIONS OF IH'S 'NFORMATION
IS THE
RESPONS'BII'ry OF THE USER EMPACT ANALyTICÁI SYSTEMS, /NC, ÁSSUMES NO RESPONS'8IT'ryFOR ACCURACY OF THE REPORTED INFORMATION NOR ANY COIVSEQUE'VCES OF /TS A PPLICATION.
EMPACT
IìXTENDED NATURAL GAS ANALYSIS (*DHA)
DHA COMPONENT LIS'T
PROJECTNO. :
COMPANY NAMEACCOUNTNO. :
PRODUCER i
LEASENO. :
NAME/DESCRIP:
*++FIELD DATA***SAMPLE PRES. :
VAPORPRES. :
COMMENTS i
COMPONENT
201407 154FIDELITY EXPLORATION
PRE COMBUST'OR TANK GAS l0:35CANE CREEK UNIT 32-I-25-I9
>l#
SPOT; NO PROBE
ANALYSIS NO, :
ANALYSIS DATE:SAMPLE DATE :
CYLINDER NO. :
SAMPLED BY ;
04
AUGUST 3,20I4JULY 28,20140320GALE MCENDREE. EMPAC'I'
SAMPLE TEMP. : 80AMBIENT TEMP.:GRAVITY :
Heliunr
Hydrogen
Oxygen/Argon
Nilrogen
Carbon Dioxide
Methane
Ethane
Propane
i-Butane
n-Butane
2,2-Dinrethylpr opane
Elhanol
i-Pentane
Acetone
i-Propanol
UnknolvuC4s
n-Pentane
t-Butanol
2,2-Dinrethylbutane
Cyclopentâne
2,3-Dirnethylbutane
2-Methylpentane
3-Methylpentane
Unkno*nC5sn-Hexane
2,2-Dinrethylpentane
Methylcyclopentane
2,4-Diruethylpentane
2,2,3-Tlinrethylbutanen-Butanol
Benzene
3,3-Dinrethylpentane
Cyclohexane
2-Methylhexane
2,3-Dinrethylpentarre
l , l -Dinrethylcyclopenlane
3-Methylhexane
I c,3-Dinrethylcyclopentane
I t,3-Dirn€thylcyclopentane
3-Ethy\rentane
I t,2-Dirnethylcyclopentane
2,2,4-Tri nrethylpenta ne
;;P2
P3
t4
P4
I5
x2I5
x3X3
U4
P5
x4t6
N5
t6
I6
t6
U5
P6
t7
N6
t7
t7
X4
A6
t7
N6l7
l7
N7
l7
N7
N7
l7
N7I8
PIANO # MOLEo/o MASS %
0.00
0.01
6.33
23.44
0.04
I 4.10370
r s.8 146
19.9377
3.094t9.1677
0.0182
0.0017
2.0269
0.0004
0.0002
0.0002
2.8s44
0.00 | s
0.0t 54
0.0940
0.0691
0.47 t3
0.2381
0,0006
0.7794
0.00s9
0.t 783
0.0146
0.0008
0.000 t
0.0771
0.0024
0.2012
0.0713
0.0260
0.0 t 25
0.0767
0.01 75
0.0 t s6
0.0022
0.0269
0.0003
Page 1
GPM @ GPM @| 4.650 t4:130
0.00
0.00
5.33
17.29
0.05
5.95670
t2.5174
23.1423
4.7338
14.0261
0.034ó
0.0020
3.8494
0.0006
0.0003
0.0003
s.42t00.0029
0.0349
0.1736
0. | 568
t.069t
0.540 I
0.001I
t.7680
0.01 56
0.3950
0.0385
0.002 t
0.0002
0. I 585
0.0063
0.4457
0.1881
0,0686
0.0323
0.2023
0.0452
0.0403
0.0058
0.0695
0.0009
4.240
5.s06I .015
2.897
0.007
0.0000.743
0.000
0.000
0.000
t.037
0.00t
0.006
0.028
0.028
0.1 96
0.098
0.000
03220.003
0,0ó3
0.007
0.000
0,000
0.022
0.00 t
0.068
0.033
0.012
0.005
0.035
0.008
0,007
0,001
0.0t20.000
4.263
5.516
1.02t
2.913
0.007
0.000
0.747
0.000
0.000
0.000
1.043
0.001
0.006
0.028
0.028
0.197
0.098
0.000
0.323
0.003
0.064
0.007
0.000
0.000
0.022
0.00 r
0.069
0.033
0.012
0.005
0.035
0.008
0.007
0.001
0.0t20.000
EMPACT Analytical Systems, lnc 365 S. Main Street, Brighton, CO 80601 303-637-01 s0
UnknownC6sn-Heptane
I c,2-DinrethylcyclopentaneMethylcyclohexane
2,2-DimethylhexaneEthylcyclopentane
2,5-Dirnethylhexane
2,2,3-Tlimethylpentane2,4-Dinrethylhexane
I c,2 t,4-Tri nrethylcyclopentane
3,3-Dimethylhexane
I t,2c,4-Trimethylcyclopentane2,3,4-Tri methylpentane
2,3,3-Tri nrethylpentane
Toluene
2,3-Dimethylhexane2-Methyl-3-ethylpentane
2-Methyìheptane
4-Methylheptane
3 -Methyl-3 -ethylpen tane
3,4-Dimethylhexane
I c,2c,4-Trimethylcyclopentane
I c,3-Dimethylcyclohexane
3-Methylheptane
I c,2t,3 -Trimethylcyclopentane
3-Ethylhexane
I t,4-Dimethylcyclohexane
I,l -Dimethylcyclohexane
3c-Ethylmethylcyclopentane
3 t-Ethylmethylcyc lopentane
2t-Ethylnìedtylcyclopentane
l, I -Methylethylcyclopentane
2,2,4-Tri methylhexane
I t,2-Di nrethylcyclohexano
I t,3-Di rnethylcyclohexane
UnknorvnCTs
n-Octane
I c,4-Dimethylcyclohexane
i-Propylcyclopentane
2,4,4-Tri methylhexane
2,3,5 -Trimethylhexane
2,2,3,4 -T etr ameth ylp en ta ne
2,3,4-Trirnethylhexane
I c,2-Dimethylcyclohexane
2,2-Dinethylheptane
I, 1,4-Trimethylcyclohexane2,2,3-Trimethylhexane
2,4-Dìmethylheptane
4,4-Dimethylheptane
Ethylcyclohexane
n-Propylcyclopentane
I c,3 c,5-Trí metþlcyclohexane2,5-Dimethylheptane
3,3-Dinrethylheptane
3,5-Dimethylheptane2,6-Dimethylheptane
I , I ,3-TlinrethylcyclohexaneEthylbenzene
I c,2t,4t-Trimethylcyclohexane
2,3-Dinrethylheptane
1,3-Dimethylbenzene (m-Xylene)
1,4-Dimethylbenzene þ-Xylene)3,4-Dimethylheptane
3,4-Dimethylheptane (2)
4-Ethylheptane
Page2
365 S. Ma¡n Streel, Brighton, CO 80601
U6
P7
N7
N7
l8N7
I8
I8
I8
N8
t8
N8
I8
I8
A7
I8
I8
I8
I8
I8
I8
N8
N8
I8
N8
l8
N8
N8N8
N8
N8
N8
I9
N8
N8
U7
P8
N8
I8
19
I9
19
l9
N8I9
N9
l9I9
I9
N8
N8
N9T9
I9
19
l9
N9
I8
N9
t9A8
A8
t9
19
ì9
0.0004
0.2216
0.00240.1 1 87
0.0074
0.004t
0.0039
0.000s
0.0060
0.0048
0.0016
0.0037
0.0002
0.0001
0.0486
0,0054
0.0015
0.03 l50.o074
0.0015
0.0014
0.0004
0.0002
0.0130
0.0183
0.0025
0.0063
0.0022
0.0003
0.0006
0.0005
0.0013
0.0003
0.0064
0.0001
0.0010
0.0575
0.0101
0.0004
0.0002
0.0005
0.0003
0,000s
o.0022
0.0002
0.0098
0.005?
0.0001
0.0003
0.00s5
0.0034
0.0006
0.0002
0.0003
0.0001
0.0001
0.0005
0.0049
0.0014
0.0013
0.0107
0.0028
0.00040.000s
0.0006
0.0009
0.5845
0.0062
0.3068
0.02220^0106
0.01l?0.0015
0.0180
0.0142
0.0048
0.0109
0.0006
0.0003
0.1179
0.0 t 62
0.0045
o.o947
0.0222
0.004s
0.0042
0.0012
0.0006
0.0391
0,0540
0.0075
0.0t 8ó
0.0065
0.0009
0.0018
0.0015
0.0038
0.0010
0.0189
0.0003
0.0026
0.r7290.0298
0.00 t 2
0.0007
0.0017
0.00 r 0
0.00 t 7
0.0065
0.0007
0.0326
0.01 92
0.0003
0.0010
0.0162
0.0101
0.0020
0.0007
0.0010
0.0003
0.0003
0.0017
0.0137
0.0047
0.0044
0.0299
0.0078
0.0013
0.00 r 7
0.0020
0.000
0,1 03
0.001
0.048
0.003
0.002
0.002
0.000
0.003
0.002
0.001
0.002
0.000
0.000
0.0r 6
0,003
0.00 t
0.01 6
0,004
0,00t
0.001
0.000
0.000
0.007
0,009
0.001
0.003
0.001
0.000
0.000
0.000
0.001
0.000
0.003
0.000
0.000
0.029
0.005
0,000
0.000
0.000
0.000
0.000
0,001
0,000
0.005
0.003
0.000
0.000
0.002
0.002
0.000
0.000
0.000
0.000
0.000
0.000
0.002
0.001
0.001
0,004
0,001
0.000
0.000
0.000
0.0000,103
0.00l0.049
0.003
0.002
0.002
0.000
0.003
0.002
0.001
0,002
0.000
0,0000.016
0.003
0.00t
0.0160.004
0.001
0.00t
0.000
0.0000.007
0.009
0,00t
0.003
0.001
0.000
0.000
0.000
0.001
0.000
0,003
0.000
0.000
0,029
0.005
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0,005
0.003
0.000
0.000
0.002
0.002
0.000
0.000
0.0000.000
0.000
0.000
0.002
0.001
0.001
0.004
0.001
0.000
0.000
0,000
EMPACT Analytical Systems, lnc 303-637-0150
4-Methyloctane2-MethyloctaneI c,2t,3-Trinrethylcyclohexane
3-Ethylheptane
3-MethyloctaneI c,2t,4c-Trìrnethylcyclohexane
l, 1,2-Trimethylcyclohexane
3,3-Diethylpentane
1,2-Dimethylbenzene (o-Xylene)i-Butylcyclopentane
UnknotvnCSs
n-Nonane
I, l -Methylethylcyclohexane
i-Propylbenzene
i-Propylcyclohexane
2,2-Dimethyloctane
2,4-Dimethyloctane
2,6-Dimethyloctane2,5-Dinrethyloctane
n-Bntylcyclopentane
3,3-Dinrethyloctane
n-Propylbenzene
3,6-Dimethyloctane
3 -Methyl-5 -ethylheptane
1,3-Methylethylbenzene
1,4-Methylethylbenzene
1,3, 5-Tri methylbenzene
2,3-Dirnethyloctane
5-Methylnonane
1,2-Methylethylbenzene
2-Methylnonane
3-Ethyloctane
3-Methylnonane
1,2,4-Trimethylbenzene
t-Butylbenzene
iBulylcyclohexaneI t-Methyl-2-n-propylcycloh exane
i-Butylbenzene
sec-Butylbenzene
UnknorvnC9s
n-Decane
1,2,3 -Trinrethylbenzene
1,3 -Methyl-i-propylbenzene
1,4-Methyl-i-propylbenzene
Sec-Butylcyclohexane
1,2 -Methyl-i-propylbenzene
3-Ethylnonane
1,3-Diethylbenzene
1,3 -Met hyl-n-propylbenzene
1,4-Diethylbenzene
1,4-Methyl-n-propylbenzene
n-Butylbenzene
1,3-Dirnethyl-5-ethylbenzene
1,2-Diethylbenzene
t-Decahydronaphthalene
1,2-Methyl-n-propylbenzene1,4-Dinrethyl-2-ethylbenzene
1,3 -Di¡ìethyl-4-ethylben zene
1,2-Dimethyl-4-ethylbenzene
1,3-Dimethyl-2-ethylbenzene
1,2-Dimethyl-3-ethylbenzene
1,2-Ethyl-i-propylbenzene
1,4-Methyl-rbutylbenzene
UnknorvnC I 0s
n-Undecane
Page 3
365 S, Main Street, Brighton, CO 80601
I9
t9
N9t9
t9
l9N9
t9A8
N9
U8P9
N9
A9N9Il0r10
Il0Il0N9It0A9Il0n0A9
A9
A9il0il0A9It0Il0It0A9
Al0Nt0n0At0Al0U9Pl0A9Al0At0Al0Al0Il0Al0Al0Al0Al0Al0At0Al0A9Al0Al0Ar0AIOAt0Al0At0Anut0Plt
0.0031
0,0043
0.0002
0.0009
0.0052
0.000ì
0.0002
0.0004
0.0044
0.0024
0.0004
0.0224
0.0022
0.0008
0.0005
0,0003
0.0007
0.000t
0.0002
0,00260.0002
0.0028
0.0009
0.0014
0.0014
0.0006
0.0009
0.0005
0.0014
0.0019
0.0002
0.0003
0.0012
0.0001
0.0033
0.0006
0.0001
0.0003
0.0003
0.0056
0.0097
0.0012
0,0003
0.0002
0.0012
0.0007
0.0001
0.0001
0.0001
0.0003
0.0003
0.0002
0.0003
0.0002
0.0002
0,0004
0.0004
0.000t
0.0006
0.0001
0.0002
0.0002
0.0004
0.0082
0.0039
0.0105
0.0t 45
0.0007
0.0030
0.0176
0.0003
0.0007
0.0013
0.0 t 23
0.0080
0.00t 2
0.0756
0.0073
0.0025
0.0017
0,00r l0.0026
0.0004
0,0007
0.0086
0.0007
0.0089
0.0034
0.0052
0.0044
0.0019
0.0028
0.0019
0.0052
0.0060
0.0007
0.001I
0.0045
0.0009
0.01 l?o.0022
0.0004
0.0010
0.0010
0,0 | 89
0.0363
0.0038
0.0010
0.0007
0.0044
0.0025
0.0004
0.0003
0.0003
0.0010
0.0010
0.0007
0.0010
0.0007
0.0008
0.0014
0.0014
0.0003
0.0021
0.0003
0.0007
0.0008
0.0015
0.0307
0.016 t
0.002
0.002
0.000
0,001
0.003
0.000
0.000
0.000
0.002
0.00t
0.000
0.0t 3
0.001
0.000
0.000
0.000
0.000
0.000
0,000
0.001
0.000
0.001
0.001
0.001
0.001
0.000
0.000
0.000
0.001
0.001
0,000
0.000
0.001
0.000
0.002
0.000
0.000
0.000
0.000
0,003
0.006
0.00t
0.000
0,000
0.001
0.000
0,000
0,000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0,000
0.000
0.005
0.003
0.002
0.002
0.0000.001
0.003
0.000
0,000
0,000
0.002
0.001
0.000
0.013
0.00t
0.000
0.000
0.0000.000
0.000
0.000
0.00 t
0.000
0.001
0.001
0,001
0.001
0.000
0.000
0.000
0.001
0.001
0.000
0.0000.001
0,0000.002
0.000
0.000
0.000
0.000
0.003
0.006
0,001
0.000
0.000
0.001
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0,000
0.0000.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.00s
0.003
EMPACT Analytical Systoms, lnc 303-637-01 50
1,4-Ethyl-i-propylbenzene
1,2,4,5-Tetranethylbenzene
1,2-Methyl-n-butylbenzene
1,2-Methyl-cbutylbenzene1,2 -Ethyl-n-propylbenzene
2-Methylindan
1,3-Methyl-n-butylbenzeue
1,3-Di-i-propylbenzene
sec-Pentylbenzene
n-Pentylbenzene
1,2-Di-n-propylbenzene
1,4-Di-i-propylbenzene
Naphthalene
UnknorvnCl lsn-Dodecano
1,2,4-Triethylbenzene
1,2,3,4,5-Pentamethylbenzene
2-Methylnaphthalene
UnknorvnCl2sn-Tridecane
UnknorvnC I 3s
n-Tetradecane
n-Pentadecane
UnknorvnC I 5s
TOTAL
BTEXCOMPONENTSBENZENETOLUENEETHYLBENZENEXYLENES
IVIOLE% WT%0.0771 0.15850.0486 0.11790.0049 0.01370.0179 0.0500
BTU@LOIY NET DRY REAL:
NET WET REAL :
IIIGH GROSS DRY REALGROSS WET REAL
NET DRY REAL:GROSS DRY REAL
t6;t483 r 6.8402
14.650 14.7301548.8 /scf '1557.3 /scf
AllAllAllAIIAltAllAIIAllAllAlrAllAnAl0ullPl2At2413
Altu12Pl3u13
Pl4Pt5
ul5
0.0002
0.0002
0.000r
0.0002
0.0003
0.0001
0.0001
0.0001
0,0001
0.0001
0.0001
0.0002
0.0001
0,0030
0.0012
0.0002
0.0001
0.0001
0.0013
0.0004
0.0004
0.0002
0.000r0.0001
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0,002
0.001
0.000
0.000
0.000
0.001
0.000
0.000
0.000
0.000
0.000
0.0000.000
0.0000.000
0.000
0.0000.000
0.000
0.0000.000
0.000
0.0000.000
0.0020.00 t
0.000
0.000
0.0000.001
0.000
0.0000.000
0.000
0.000
I 00.00000
0.0008
0.0007
0.0004
0.0008
0.0012
0.0003
0.0004
0.0004
0.0004
0.0004
0.0004
0.0008
0,0003
0.0123
0.0054
0.0008
0.0004
0.0004
0.0053
0.0019
0.0019
0.00r00.0005
0.000s
100.00000
TOTAL BTEX 0.1485 0,340"1
RELATIVE DENSITY (AlR=1 ):(cALc: GPÅ srD 2t45 erP-t7 @r4.6s6 &60 D COMPRESSIBILITY FACTORi(DETAILED H|DïOCARBON AN¿IL|S|S/NJ t993) ; ASTÀI D67i0
TH]S DÅTA HÅS BEEN.ÅCQUIRED THROUGH /PPLICÅTION OIl CURRENT S1,4TE-OII-THE4RT,INALYTICÁL TEC¡TNIøUES,
THEUSEOTTIIISINFOR\UTIONISTIIERESPONSIBLIÍ'OFTHEUSEL EIIP'ICTANILY||CA¿Sysrrils,lSsU/tlfSlvoRESPONSIDLITY FORACCURJICY OFTHE REPORTED INI:ORi'IITION NORÅNI'CONSESUENCES OF I7lS ÅPPLICÅTION.
Page 4
365 S. Maln Street, Brighton, CO 80601
1521.7 hcr1684.7 /scf1655,2 /scf
15495.8 nh16851.7 nb
'1530.2 /scfI 693.9 /scf'1664.4 /scf
15580.4 /rb16943.8 nb
1.31070,99204
EMPACT Analytical Systems, lnc 303-637-01 50
FILED
BEFORE THE BOARD OF OIL, GAS AND MININGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FOR AGENCYACTION OF FIDELITY EXPLORATION &PRODUCTION COMPANY FOR AN ORDERAUTHORIZING THE FLARING OF GAS IN EXCESS OF
THE AMOUNTS ALLOWED UNDER UTAH ADMIN.coDE RULE R649-3-20(1.1) FROM THE CANE CREEKUNIT 32-I-25.19 WELL LOCATED IN SECTION 32,
TOWNSHIP 25 SOUTH, RANGE lg EAST, SLM,GRAND COUNTY, UTAH
CERTIFICATE OF' SERVICE
Docket No. 2015-01I
Cause No. 196-45
Fidelity Exploration & Production Company ("Fidelity"), acting by and through its
attorneys, MacDonald & Miller Mineral Legal Services, PLLC, hereby certifies that the
following constitutes, to the best of Fidelity?5 knowledge, a list of all parties whose ,,legally
protected interests" will or may be affected by Fidelity's Request for Agency Action dated
February 10,2015 and on file in the captioned cause (the ,'Request',):
ExxonMobil CorporationAttn: Ken Hilger, CPLP.O. Box 4610Corp-Wgr'-702Houston, TX 77210-4610
Front Range Energy Investors LLCAttn: Land Depaftment324 Gañen StreetGolden, CO 80403
FREI LLC-[Attn: Land Department324 Gañen StreetGolden, CO 80403
State of Utah School and Institutional TrustLands AdministrationAttn: Ms. Lavonne Garrison675 EasI500 South, Suite 500Salt Lake City, UT 84102
Bureau of Land Mgmt, - Utah State OfficeAttn: Roger L. Bankert440 West 200 South, Suite 500salt Lake city, uT 84101
Bureau of Land ManagementMoab Field OfficeAttn: Eric Jones
82 East DogwoodMoab, UT 84532
The undersigned furthel certifies that he caused true and colrect copies of said Request,
to be mailed, propelly addressed, postage pre-paid, and certified with return receipt r.equested,
to the above named parties this 12fl' day of February, 2015.
MIcDONALD & MILLER MINERALLEGAL SERVICES, PLLC
Esq
7090 S. Union Park Ave., Ste. 400Midvale, Utah84047Telephone: (801) 676-0050Facsimile: (801) 676-0051E-Mail: [email protected]
Attorneys for Petitioner Fidelity Exploration &Ploduction Company
FMM:nrhk1050.06
2
n LED
BEFORE THE BOARD OF OIL, GAS AND MININGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FOR AGENCY
ACTION OF FIDELITY EXPLORATION &,
PRODUCTION COMPANY FOR AN ORDER
AUTHOzuZING THE FLARING OF GAS IN EXCESS OF
THE AMOUNTS ALLOWED LINDER UTAH ADMIN.coDE RULE R649-3-20(1.1) FROM THE CANE CREEK
UNIT 32-1-25-19 WELL LOCATED IN SECTION 32,
TO'WNSHIP 25 SOUTH, RANGE 19 EAST, SLM,GRAND COUNTY, UTAH
PETITIONER'S EXHIBITS
Docket No. 2015-011
Cause No. 196-45
Pursuant to Utah Admin. Code Rule R641-105-500, Petitioner Fidelity Exploration &
Production Company ("Fidelity"), by and through its counsel of record, MacDonald & Miller
Mineral Legal Services, PLLC, hereby respectfully submits the following exhibits intended to be
offered into evidence in support of its Request for Agency Action (the "Request") at the March 25,
2015 hearing on this cause:
EXHIBIT (4" - Fidelity's potential witnesses' resumes (collectively 7 pages):
o Wes Adams - Landmano Ethan Ngo - Reservoir Engineero Dina Brown - Senior Environmental Engineer
EXHIBIT ((8" _ True and correct copy of the Board's Second Supplemental Findingsof Fact, Conclusions of Law and Order entered on December 18,
2014 inCause No. 196-44 (11 pages).
Plats of Cane Creek Unit Area and location of the CCU 32-l-25-I9V/ell in relation to the Deadhorse Lateral Pipeline, and existinggathering system and possible additional wells to supportconstruction of, and location of possible, gathering line (collectively2 pages).
EXHIBIT '(C'' _
FMM:mhk I 050.06
EXHIBIT "D" -
EXHIBIT "E" -
EXHIBIT "F" -
EXHIBIT "G" -
EXHIBIT "H" -
EXHIBIT "Z"-
CCU 32-1-25-19 Well initial completion report (2 pages).
Chemical analysis of gas produced from CCU 32-1-25-19 Well (also submitted as Exhibit "1" to the Request) (12 pages).
CCU 32-1-25-19 Well production and flare forecasts (2 pages).
Gas gathering economics (2 pages).
Flaring alternative analysis (1 page).
True and correct copies of return receipts indicating receipt by, or of the mailings returned as undeliverable to, or of USPS inquiries as to the status of mailings to, parties identified in the Certificate of Service dated February 12, 2015 on file in this Cause of the Request, as of February 20, 2015 (to be supplemented prior to hearing) (collectively 3 pages).
Respectfully submitted this 2Yd day ofFebruary, 2015.
MACDONALD & MILLER MINERAL LEGAL SERVICES, PLLC
Attorneys for Petitioner Fidelity Exploration & Production Company
2
EXHIBIT A
WESADAMS
99 Corona Sh·eet, Apt. 504 Denver CO, 80218 (720) 883-8920, [email protected]
SUMMARY
I am seeking a challenging role where I can improve operating efficiencies, grow production and increase leasehold acreage. Provide sh·ong attention to detail and execute land capacities of Federal, State and Fee ownership. Establish camaraderie in a team enviromnent; build rapport with agencies and interest owners. Identify problems quickly to solve one-off situations.
EXPERIENCE, LEADERSHIP AND ACCOMPLISHMENTS
Fidelity Exploration and Prodttctiou Compauy: Laudmau February 2014 - Preseut
Paradox Basiu - Caue Creek Uuit, Utah - Oil Play; Federal Unit comprised of53,000 acres, 10% State East Texas Basiu- HBU, Gas and Oil Piny comprised of9,600 acres Powder River Basiu- HBU, HBP, Fee- Oil Play comprised 15,000 acres
Set up meeting with BLM and SITLA to amend the Unit Agreement for the 2015-2016 years. Given the inability to drill economic wells in the Cane Creek Unit at $50 dollar oil, I worked to change our drilling and completion obligations in order to save an estimated $8-10 Million from Capex.
Presentations to Executive Management on the following: Drilling AFE and well review prior to operations. Land objectives, sh·ategy for development. Marketing efforts of Fidelity to Goldman Sachs.
Testified at the Board of the Utah Division of Oil, Gas and Mining (UDOGM), Granted an extension to fla.re unit wide gas up to 4MMCF / day, until the completion of our gathering line and gas processing plant. I worked with legal counsel to set up and organize the exhibits to request agency action and hearing docket.
Transportation Agreement to flow gas, critical to operations of oil production. Worked alongside legal counsel, facilities engineers, asset managers, financial managers and third party pipeline operators to create terms for shipping our residue gas to market. Facili.ties constituted $30 Million in construction, flaring is heavily regulated so plant and pipeline were cost of doing business .
Severance Tax Exemptions Led groups effort to extend 5% State Tax Credit on wildcat wells; argue for separate containers due to pressure difference when less than one mile from offset location. Large revenue savings had significant impact to bottom line and helped in the cost reduction enviromnent of $50 oil.
Drilling schedule; making sure the inventmy is ready to go and that all disciplines are aware of their responsibilities to get all contingent options prepared.
Ensure depth ownership, drilling obligations, enviromnental affairs, land access and conh·acts are met. Manage DTO preparation, land diligence and Unit Agreement commihnents.
Participating Area revisions, per BLM Unit wells based on approved economic wells using Aries analysis and drilling survey plats. Includes compiling exhibits of lands/ lease detail in the captioned area/percentage of split ownership.
Predicated on Paying Well Determinations, applied for within 6 months of completion of wells . Include completion report for drainage calculations and lease royalty obligations via HBU acreage.
Exploratmy Unit formation experience: Currently in the process of; Enviromnental Impact Statement (EIS); acquisition of new leasehold, committing open leases held to Mater Leasing Plan (MLP), joining parh1ers, putting together an area in depth meeting with the BLM, SITLA and parhlers.
Cure Title Opinion requirements prior to drilling; ensure leases are valid via rental payments, ensure provision compliance, correct deficiencies, and follow ownership for proper assigmnent conveyance.
f!X · i· T A
Communication with field personnel, per use of right-of-way, easement and consh·uction grant as they relate to Joint Operating Agreements, Unit Agreements, Environmental Assessments and APD's.
Prepare Well Announcements, surface-landing-bottom-hole coordinates, drill block acreage WI & NRI.
Southwestem Energ~j: Contract Field Landman Rocky Motmtain Region: November 2013- February 2014
Exploration prospect; Title from patent to present in Southeast Utah and Southwest Colorado, open acreage verification, production checks, and lease analysis.
Support field crew with challenges presented through title and logistics required to achieve completion of project.
Systems Petroleum: Contract Field Landman Rocky Mountain Region: June 2013- November 2013
Acted as point of contact for crew and Lessors in field, solving breaks in chain, lease assignment analysis per NRiand WI.
Exploration prospect; running Title from patent to present in Southeast Wyoming, negotiating oil and gas leases: bonus/ royalty/ length/ and clauses. Supporting with town halls, and establishing compliance of legal conveyance for curative measures ..
Magellan Petroleum: Contract Itt-House Landman Rocky Mountaitt Region: JanuanJ 2013 -May 2013
Acquisition of production in Central Eastern Montana- Primary focus was to analyze and convert leases on the 20k acre East Poplar Unit from Sherware software into BOLO software. The E.P.U. consists of Indian, Federal and Fee leases, signed prior to production occurring in 1950. Responsible for reviewing N.R.I., W.I., and Delay Rental Payments and interpreting what was in the P.A. (post contraction of unit)
Analysis of relinquishment by B.L.M. and subsequent Patents to Indian allottees, track missing heirs, reconcile failed rental and royalty payments to beneficiaries.
Apache Corp: Contract Field Landman Mid Continent: June 2012- January 2013 (Cotttract with TCO)
Exploration prospect: Title from patent to present in Northwest Kansas: Part of team who leased 580,000 net acres.
TakeOffs and Mineral Ownership Reports using Excel and Word.
Charles Schwab: Finattcial Broker Series 7 and 63 Licensed: 2010 - 2012
Study market mechanics, guide clients through trading strategies, asset allocation and financial planning.
Place h·ades for clients on the phone, provide education on brokerage products and build rapport with clients to offer services that increase asset growth for them and Schwab.
Candidate for Chairman's prestigious club my first year: Top 10 percentile of Brokers Nationwide, per performance metrics used company wide
AHA Inc. -Adams Heating and Air Conditioning Operations Manager: 2005- 2010
As a part-owner in a family company, I served as project manager on construction sites, bid jobs, maintained profit margins, scheduled installs, built material/ equipment packs for plumbing and HVACjobs.
EDUCATION
Metro State College of Denver- B.S. in Business Administration Finance Concentration - 2005
Memberships: AAPL, DAPL, DADO A. Certifications: RPL- (pending), Series 7, 63- Financial Broker
1617 6 E Progress Pl. Centennial, CO 80015
Ethan An Ngo 281-513-5552 [email protected]
Reservoir Engineer: Fidelity Exploration and Production Company, Denver, CO July 2014- Present
~ A&D ~ Currently providing reservoir engineering support for the Paradox Basin asset team
• Creating RTA and nodal models to better understand and predict well perfonnance • Helping team identified stimulation oppmtunities
~ Worked and helped close the Big Horn Basin divestiture in Nmth-Central Wyoming ~ Collaborated with the exploration team to assess opportunities that comes through the door
Reservoir Engineer: Liberty Resources, LLC, Denver, CO Apr 2013- Jun 2014
~ Business Development ~ Assessed and valued opportunities that fit and meet corporate strategies and pmtfolio goals ~ Evaluated oppmtunities beginning from virtual data room to forecasting existing wells, building type
curves, developing development plan, and generating cashflow models ~ Support team to streamline allocation process and expedite signing of purchase sale agreement ~ Helped build database tool for entire state ofNotth Dakota to quickly look at well performance and
completion designs for use as litmus test to value oppmtunities ~ Build analytical models to better understand well spacing and well interactions
~ Williston Basin- Bakken Oil Shale Resource Play ~ Coordinated 3rd patty Bakken completion simulation study to better understand and optimize completion
designs
Reservoir Engineer: Newfield Exploration Company, Denver, CO Apr 2011- Apr 2013
~ Williston Basin- Bakken Oil Shale Resource Play ~ Designed well tests to determine early-time and mid-time press~1re communication between offset wells ~ Created rate transient models to help team better understand flow regime, gain confidence in stimulated
reservoir volume values, and approximate EUR through flowing material balance ~ Designed chemical and radioactive tracer job to test offset and inter- well communication ~ Coordinated and helped progress Eclipse simulation modeling effmts amongst multidisciplinary teams and
helped define modeling objectives, workflows, and provided guidance and alignment with team ~ Led PVT acquisitions and study on the Bakken/Three Fork fluid characterization to better understand
reservoir performance. Data was also used in a reservoir simulator ~ Developed Bakken/Three Forks type curve and performed reserve adds and revisions ~ Developed tools to help team work more efficiently and save time on most day-to-day processes and
workflows -this encompasses reservoir surveillance and offset well evaluation ~ Created nodal models to optimize well's operational performance
Senior Reservoir Engineer: ExxonMobil Production Company, Houston, TX Feb 2008- Mar 2011
~ Santa Ynez Unit Highly-Fractured Chert Heavy Oil Reservoir Simulation Engineer ~ Developed and progressed full-field parametric study model to assess $600MM project with potential of
200+MMBOEs • Built segment and full-field model to test depletion concepts • Developed API trends, reservoir propetty adjustment multipliers, and hydraulics tables for historical and
prediction periods for simulation model • Collaborated with research, geoscience, and reservoir engineers to create "base" case model • Designed and ran sensitivity cases to evaluate key uncertainty variables • Benchmarked simulation results with traditional analog drillwell assessment approach
~ West Texas- Midland Area Carbonate-Chert Tight Gas Reservoir Engineer ~ Evaluated drillwell oppmtunities and assessment using both analytical reservoir modeling programs and
analog based approach to develop type curves for economic analysis
~ Worked with JV pattners to maximize reserves and maximize profit for ExxonMobil ~ Generated workover opportunities that included recompletions, installing down-hole injection systems,
optimizing gas-lifts and plunger-lifts, and increasing productivity by routine wellbore clean-outs ~ Performed incremental economics using PEEP to assess drillwell and workover opportunities ~ Revised ~ 8 MMBOEs of reserves driven by new drill wells, recompletes, N take, and well performance ~ Mento red intern on reserves study of a field with the potential to affect~ 10 MMBOEs ~ Performed day-to-day reservoir surveillance
~ East Texas- Carthage, Halletsville, and Webster Area Reservoir Engineer ~ Conducted competition study of tight gas sandstone reservoir to test profitability of new field rules and
optimize depletion strategy ~ Worked with field operators to optimize down-hole injection systems to maximize gas production per well
P E Internship: Myanmar Petroleum Resource Ltd. E&P (MPRL E&P), Myanmar
~Performed political risk assessment for MPRL E&P ~Updated MPRL's economic model and incorporated political risk into model ~Interpreted 3D seismic data and logs, and digitized fault block contours ~Studied drilling, production, well site maintenance/service, and geology in the field
EDUCATION Colorado School ofMines (CSM); Golden, CO
~ ME Petroleum Engineering; Cum GPA 3.7 Dean's List ~ MS Int'l Political Economy ofResources; Cum GPA 3.8 Dean's List
• Special interest in China and Southeast Asia ~ BS Civil Engineering; GPA 3.5 Dean's List, Honor Roll
STUDY ABROAD WHILE AT MINES
Beijing Language and Culture University (BLCU), China
~ Intensive Chinese language and culture study
University of Adelaide, Australia
~ Study abroad, Petroleum Masters courses
Ecole Speciale Des Travaux PublicJEcole Polytechnique Fran~ais, France
~ Intensive French language and culture study
The University of Hong Kong, China SAR ~ Study abroad GE3 exchange program
ACTIVITIES-INTERESTS
~ Rock Climbing, Running, Swimming, Snow Boarding, Wrestling ~ Traveling, Reading, Music
Language Skills: Chinese: Mandarin, Chaozhou; French; Cambodian
Summer 2006
Double Masters
May 2007 Dec 2007
May 2004
Spr/Fall2006
Spring 2005
Summer2003
Fall2000
DINA E. BROWN
Education
Fidelity Exploration & Production Company 1801 California Street, Suite 2500, Denver, CO 80202
[email protected], 720-917-3069
• M.S. in Forest Science- Oregon State University, Corvallis, Oregon. Minor in soil science and water resources. Thesis title: Denitrification and Vegetative Uptake in a Pasture, Poplar, and Native Oak Riparian Buffer Area.
• B.S. in Civil Engineering- Texas A&M University, College Station, Texas. Emphasis in environmental engineering.
Professional Registration
Certified Professional Soil Scientist (CPSS) No. 32073, ARCPACS/Soil Science Society of America, November 2004- December 2015.
Employment History
Senior Environmental Engineer. Fidelity Exploration & Production Company, Denver, Colorado. March, 2013 to present.
Provide leadership for permitting and compliance in the Paradox Field (Utah), a controversial oil play on federal and state land situated between two national parks and a state park. Lead and participate in multi-disciplinary teams of consultants, contractors and internal staff responsible for land, exploration, construction, drilling, completions, facilities, production, and reclamation. Responsible for strategic planning and tactical implementation of company's community relations program involving multiple stakeholder groups including federal and state political leaders, government land management agencies, local government, non-government environmental organizations, community advisor consultants, and the general public.
Specific Responsibilities: • Development of Strategic NEPA Initiatives- Develop drill pad site selection process by using spatial
analysis techniques to model viewshed impacts, and avoid highly visible sites, wildlife stipulation areas, archaeological sites, surface drainage features, and no-surface-occupancy areas. Develop strategy to obtain variance from Onshore Order #1 to delay interim reclamation to allow for multi-well pad drilling.
• NEPA Analysis- Plan and prepare NEPA compliance program for seismic, drilling, pipeline right-of-way, and gas gathering projects. Liaison with Bureau of Land Management for all NEPA related activities including on-site meetings, pre-construction meetings, and project compliance monitoring. Manage Application for Permit to Drill (APD) preparation for initiation of NEPA analysis process.
• Federal Permitting and Compliance Support- Working with both Exploration and Development teams, provide strategic guidance on federal permitting, develop Surface Use Plan of Operations template, and manage resource consultants (archaeology, wildlife, paleontology) and operations staff to ensure APD Conditions of Approval compliance.
• Facility Design Support- Working with facilities, surveying, operations, and drilling and completions teams, design pad layout to allow for multi-well development, maximize operational flexibility, meet safety requirements, and maximize interim reclamation.
• Spill Planning and Response- Manage compliance with Spill Prevention, Control and Countermeasure (SPCC) rules including preparation of plans, field training, and site audits. Provide internal and external spill reporting and response support to field operations.
• Reclamation- Working with operations, construction, and reclamation contractor, lead site stabilization, interim and final reclamation efforts to ensure compliance with BLM requirements.
Dina E. Brown Page 2
• Acquisition Support- Provide due diligence support for acquisition activities by assessing surface use potential (i.e., wildlife issues, etc.) on federal lands, researching and reviewing existing environmental documents, and conducting environmental site assessments.
• Governmental/Public Affairs- Participate in county led multi-stakeholder initiative to provide guidance to congressional leaders for crafting legislation to avoid area national monument listing.
Environmental Specialist. Talisman Energy USA Inc. - Eagle Ford Delivery Unit, The Woodlands, Texas. July, 2012 to March, 2013.
Provided environmental program development, implementation, training, and assurance to help delivery unit conduct business and to limit risk to the company. Worked with construction, drilling, completions, operations and facilities teams within the delivery unit to build necessary environmental management programs.
Specific Responsibilities: • Wetlands Assessment Program - Developed a pre-construction wetlands review program to ensure federal
compliance with Section 404 of the Clean Water Act. Evaluated existing locations, including legacy sites, for compliance and obtained after-the-fact permits when necessary.
• Spill Planning and Response Program - Developed and implemented SPCC program including plan preparation, field training, internal and external spill reporting, and spill remediation.
• Compliance Gap Assessment- Audited all operations within the Eagle Ford to determine regulatory compliance status.
• EPCRA (SARA Title Ill) Program- Developed and maintained Emergency Planning and Community Right to Know Act reporting program. Developed training program for field level drilling, completions, and operations foremen.
• Waste Management Program - Developed a waste management program to track wastes generated and identify appropriate waste receivers. Built a waste receiver auditing program to ensure waste receivers are environmentally compliant and financially sound so as to limit risk to the company.
• Baseline Sampling Program - Developed a baseline sampling program of private water wells to conform to Talisman's Shale Operating Principles.
Environmental Specialist. Talisman Energy USA Inc. - Marcellus Delivery Unit, Warrendale, Pennsylvania. October, 2010 to June, 2012.
Provided environmental program development, implementation, training, and assurance to help delivery unit conduct business and to limit risk to the company. Worked with construction, drilling, completions, operations and facilities teams within the delivery unit to build necessary environmental programs. Was able to socialize compliance and regulatory requirements and create workable solutions in partnership with the delivery unit.
Specific Responsibilities: • Waste Management Program - Developed, implemented and conducted training for a waste manifesting
and tracking program. Built and maintained data management program to enable completion of compliance waste reporting.
• Compliance Waste Reporting - Completed compliance waste reporting including, state mandated biannual residual waste reporting, state mandated annual residual waste chemical analysis reporting, and, EPA requested produced water quarterly reporting.
• Waste Receiver Auditing Process - Developed and implemented a waste receiver review and auditing program.
Dina E. Brown Page 3
• Waste Receiver Relationship Building - Developed and maintained strategic relationships with area waste receivers. With the support of drilling and supply chain, was able to partner with waste receiver to develop a new process to achieve a -10% reduction in drilling waste disposal costs.
• EPCRA (SARA Title Ill) Program Development- Developed and maintained Emergency Planning and Community Right to Know Act reporting program. Developed and delivered training program to field level drilling, completions, and operations foremen.
• Baseline Sampling Data Management System - Developed and implemented an environmental database system, using EQuiS database software, for management of state mandated predrill private water well sampling. Provided leadership to the Marcellus Shale Coalition's effort to create an industry-wide EQuiS database for the submittal of predrill sampling results to the state.
Principal Scientist. KC Harvey, Inc., Bozeman, Montana. January, 2002 to June, 2009.
Provided environmental management consulting services to the oil and gas and mining industries. Managed projects and served as senior client contact. Developed strategies for solving resource management issues and for obtaining/maintaining environmental regulatory compliance. Conducted field work to collect natural resource data, including soil, water, and vegetation information. Analyzed data, researched alternatives, and prepared reports. Communicated results to corporate executives, client management and technical staff, regulatory agencies, and the public, especially to landowners with a vested interest in the results of issue resolution.
Served as senior business manager for KC Harvey, Inc. Formulated business development plans and company growth and expansion plans. Participated in successfully merging the company with a large construction company. Supervised and mentored seven staff scientists.
EXHIBITB
I LED bE.Q 1 8 2014
S6Cfi~~'(, . ~QARO OF OIL; GAS & MINI~G
BEFQRE THE BOAIU> OF OIL, GAS AND MINING DEPARTMENT OF NATURAL RESOURCES · ... ·· ·· ·· .. . . · .. • ... STATEOFUfAII . . ... · .. · .. • .. .
IN tHE MATTER Of TlfE REQUEST FOR AGENCY .. Acn<)l'{ Of FttiELlTY m(PL6RA.ti6N .& PRODUCTION COMPANY FOR AN ORDER M6niFVING THE . s~~IES OF tAUSE NO. i 96 oiWE.Rs AND A.iFrHoroziNG rAE ii:AR!No oF .ciks IN exc'ess. QF TH~ AMOmns AJ-j)JW~D l_mr)f;R, IJTAH AQrvpN~ CODE RULE.\ R649.:3 ~~Q(J,l) qi-J A UNIT~WIDE BASIS FOR THE CANE CREEK FEDERAL
·~~~:j~~fsiJ~ITtiL~2A~db~j.· rt~a~s i; THR9UGH 2o EAST; SL.Mi GRAND A.Nb sAN 1lJAN COUNTIES, UTAH
Pock¢tNo. 2013~011 .
Cause N6, J 9644
fet~tioner Fidelity ExploraHol) .~ j-lroductim1 ¢O.trtpany's . ('~Fidelity's'') Seconcl . ' . . . . . . . . . .. . . ..
S~ppleinenhll ReqUest for Agency A.9ti9ri fjl~d 6ii Octq~~t ~o •. 2014 in th~s Cause (the
''Second Supplemental Request") came on for heating before the Utah Boa.td of Oil, qas
and Mining (the ''Board'') on Wednesday, P.ecember 10,~014; a:t approximately 9:00
ELm., in the J\uditmium of the Ut(lh Depaxtmeht of Naturctl R¢s(Jurces Btiildlng in Salt
L~ke City. The following Boatd mem.~ers \Vyre v.re~ent ilnd p~rHcipated at the hearing:
ChairmanRuland J. Gill, Jt., kelly L. Payne, Carl F. Kendell~ Chris D. Ha11sen, Mitha~l
R Brown, SusanS. Davis and Gordon L.l\1oon. f.he Board was fepr~sented by Michael
S. Johnson, Esq., Assistant Attorney G~f1~raL
Testifying on behalf of Fidelity were Wes Adarns ~ Land TechniCian, and
Michael J. Keller- Environmental Affairs Manager. Frederick M. MacDonald, Esq., of
EXHIPIT B
and for MacDonald & Miller Mineral Legal Services, PLLC, appeared as attorney for
Fi(jelity.
John Robin~on Jr., Esq., Assistant Attorney General, appeared as attorney for the
Diyision of Oil, Gas and Mining {tile "Division''). Tll.e Division did not tile a responsive
pleaqing to the Seco11d Supplemental Request and; at the hearing, expres~ed no objeetiop.
to the granting thereof.
Jim Davis, :Field Operations Supervisor of the Utah Scnool and Institt1tiopal Trust
Lands Adll1inistnition (''TLA';), made a statement il1 support of tJ:u~ granting ofthe
Second Supplemental ~¢quest. Tile statement was not ma(je ]lncleroath.
Beth.Ransel, Fi~ld.Manager ofthe Moab Field Office, and ~anc.e P()rter, Dist~ict
Manager of the Canyon ~ountcy District Offic~, of the Bureau of Land Mai1age1llent
(''BLM'') made statements in support ofthe granting of th~ Second Supplemep.tal Request
and answered questions from the Board. Neither the statements made nor answers
provided we.te made under oath.
No other p(;lrty filed a response to the Second Supplemental Request and J:lo .other
party appeared ot participat~d at the hearing.
The Board, having considered the testimony presented a:n<l the exhibits received
into evidence at the hearing, being fully advised, and for good cause, hereby makes the
following findings of fact, conclusions of law and order in this Cause.
2
FINDINGS OF FACT
1. Fidelity is a Delaware corporation in good standing with its principal place
of business in Denver, Colorado, It is an indirect sub$idiacy of MDU Resources Group,
Inc. Ftdelity is duly qt}alified to c()nduct business in the State ofUtah, ~nd is fully and . . . - . . - . .
appropriately bon,ded with all relevant Federal and State of Utah agen,cies.
2. The Cane Qreel,( Federal Exploratory Unit (the "U11if'), administered by the
BLM;; was approved effective April J~, 2002 and is curJ:ently comprised oft4e fQllowing
Gnirtd and San Jt1ari Counties, tjta,h lailds:
Towrishlp 25 South, Range 18 East, SLM
Sections 1·l6indusive: All Section~ 21-24 incl~sive: All
Township 25 South~ Range 19 East, SLM
S~ctions 6.;.9 inclusive: All Sections 14-36 iriblti~ive: All
Township 26 South, Range 19 East, SLM
Secti()n,s 1-3 inclusiye: 1\ll Sections 10-15 • inclusive: All Secti~ns 22-?7 incl~Sive: All Secfio,ns 34-36 inclusive: All
Township26 South; Range 20 East, SLM
Sections 5-8 inclusiv{}: All Sections 17-21 inclusive: All Sections 28-33 inclusive: All
3
( contain,ing 53,4 74.19 acres)
There currently are three Cane Creek participating af¢a$ within the Unit Fidelity
currently serves f!S Unit {)perator.
3. The oil and gas within, the Unit Area is approximately 90% Federally
owned, With the teiJ.laining 10% owned by the State oftJtah (administered by TLA).
4. Pursuant to ~h~ Board;s Sl.lpplefuenti:tl Order entered on Jl1ne 13, 2914 in
this Cl;lUSe (the ''~l.lpple!Jl:ental Order''), the Board authorized FidelitY or its successot(s)
as operator <rf the Unit, to flf!re gas on a Un.it~wide basi~ tln:otigh December 31, 4014 , or
the cornpletion, GOfl1mi~siol1il1g aJ1cl placing into permanent sezyice of the Dead Horse
Lateral Pipeline and Processing Plant and connection of in,divi4ual wells through the gas
gathering system, whichever occurs first, provided:
a) the aggregate amour~t flared shall hot exceed 4;000 MCFPD; and
b) the ainounf flared fi;om fillY one well shall notexceed 775 MCFPD.
The Board also expressly retained jurisdiction over this Cause~
5. The BLM, by Letter dated August 6, 2014 and pursuant to NTL-4A,
granted Fidelity a,uthority to flare in accordance with the terms and conditions of the
Supplemental Order.
6. The December 31, 2014 date was predicated upon additional National
Environmental Protection Act analysis required for the gas gathering system necessary to
4
commis~ion and supply the Dead Horse Lateral Pipeline and Processing Plant (which
would eliininate the need for further flaring), and the BLM's representation at the hearipg
from which the Supplemental Order issue<I that it would issl.le a final deCision ort the Gas
Gathering System Environmental Assessment (the ''Gatheting EA'') by Qctober 1, 2014.
An October I, 2Q 14 BLM approval of the Gathering EA cot)stituted a "worse.; case''
scenario which would pJlsh Fidelity's estit11,atdd po111pleti()n date to its very limit
(De¢ember 31, 2014).
7. Ori October 2, 2014, tl"le )3LM issued its Record of Decision for the
Gathering EA approving construction ofthe gatherii}g sy~tein with specified conditions.
Am<:mg those conditiops, which Fidelity h~d n,ot previol!sly discussed vvith the :SLM or
expeCted, were a new Compliartce Moriitori11g Plan (''CW"), different from the CMP
used for the Pipeline construction, arid a t11ree-week prior written. notification to
recreatio11al permittees.
8. On October 7, 20 14; Fidelity provided the requisite written notice to
recreational permittees and, on Octobet·16, 2014, Fidelity a11d the BLM agreed upon the
terms of the CMP. Construction on the gathering system began 011 OCtober 20, 2014.
9. On October 31, 2014, the Squthetn Utah Wilderness Alliance and the Sierra
Club filed a petition for BLM State Director Review of the Record of Decision for the
Gathering EA. On December 1, 2014, the BLM State Director upheld the Record of
5
Decision oh the Gathering EA. Although no stay of the Record of De. cisio. 11 ha. s. been . . . . ' . .
requested to date, the Board is cogntzatit that the limitations period f()r ~ppeal ()fthe St{lte
Director's Decision 4as not yet run a11d that there is a potential for further delay.
10. A~ o:f the date of the pe~ring, FidelitY tepoJ.ied the gathering system for ()tie
well (the CClJ12..,1) had been installed and is ready to. be c6IT1!llission~d, and that the
remaining Phase I gathering sy~t~lll.c:onstrU<#ion will p~ C()mpJeted ill wid-January, 201Q.
Approximately 75 " 80% of existing Uriit pto4i:tPt~on is ~·equired for t11e Plant to be
cqmfliissiorted. Presuming no other delays beyond Fidelity's reasonable control are
encountered, Fidelity expects the PlaJ:it ~tid Pipeline. to be commi~sioned. and fully
operational by Match 31, 2015. Fide.lity has remained diligent i1;1 its efforts to complete
and commis.~ion the Plant and Pipeline, which remain t4e only practical ap.d viable
alternative to fl(lrihg.
11. Fidelity has represented that it!; projected production through March 31,
201 ~ will not require any adjustment to the flaring rates authorized uri<ier the
Supplemental Order,
12. A copy ofthe Second St1ppleni¢11tal Request was mailed, postage pre.:.paid,
a11d properly addre~sed to all mineral, leasehold and production interest owners within
the Unit to their last addresses disclosed by the appropriate BiM, TLA and Grand and
6
. ,. San Juan C:::ounty realty records, and to the TLA and Utah State and Moab Fit:;ld Qffices
oftheBLM,
13. Notice of the filing of the Second $1Jpplementa1R~quest and of the. hearing
hereon was d\lly published on November 16, 2014 in the Salt take Tribune arid Deseret
Morning News, on November 19, 2014 hi the San Juan Record and ()n November 20,
2014 in the Moil,b Tjm~s ~ Indepei1d<?rit.
14. The vote of the Board :rvi~mbers presep.t an<.l particiPa.ting i4 the he~ring on
this Cause was u!la1ljp1Ql1S (7 ,.O). ip. favqr of granting the ~~~o.nd $upplemental ~equest
CONC:LlJSIONSOFLAW
1. the Board has jurisdiCtion over all matters covered b)' the Sec()rid
Supplemental Request and ali interested parties th~rein, and has the poWer and authority
to render the order herein set forth pursuant to Utah QodeAnn. §§40-6-5(3)(f) and l]tah
Admin; Code Rule R649-3,;;20(5).
2; The t~rms and conditions of flaring set forth herein are fair, just and
reasonable tinder the circumstances and will minimize waste to the fullest extent possible
until the gathering lines, Pipeline and Phmt are fully in service.
3. Fidelity has sustained its burden Qf proof, demonstrated good cause, and
satisfied all legal requirements for the granting of the Second Supplemental Request as
ordered below.
7
ORDER
Based upon the Second Supplemental Req_uest, testimony 11nd eyidence submitted,
and the findings of fact and conClu.sio11s o:f law stated above, the Board hereby ordefs:
1. The Second Suppl¢mental Request in this cause, .as cqpformed tp the
testimony arid other evidence provided at the hearing, is granted.
4. The Suppieme11taJ Ord~r .·is hereby e#ended to allow Fidelit:y, or its
su.ccessor(s) as op¢tatot qftlle Unit, to :flare gil,s on a Unit~wide basis~ with anaggtegate
rate limitation of4,000 MCFPD and an individual we{! r~te lirrtitatioll of 775MCI'P:Q,
through M11rch 31, 2Qt~, or tile compieti()n, commissioning and plasiti~ into penn1.111ent
service of·the Dead Hor~e IAiter(ll PipCiil}~ f!,n,d Processing Phmt and connection qf
i11dividual wells thrc)Ug,h the gas g,athering system, whichever occurs first.
3. :Pursu.ant to Utah A<Jrpin. Code Ruies R641 and Utah .Code Aim, §()30,;4'"
204 to 208, the Boar<l has considered a11d deCided this matter as a formal adjudication ..
4. This Order is based excl~sively on evicience ()f record ill the adjudicative
proceeding or on facts officially noted, and constitutes the signeq written order stating the
Board's decision and the reaSO!lS for th,e dycision, aJJ as required by the Administrative
Procedures Act, Utah Code Ann. §63GA-208 and Utal). Administrative Code
Rule R641.-1 09.
8
5. Notice re: Right to Seek Judicial Review by the Utah Supreme .Court or to
Request Board Reconsideration: As requited by Utah Code Artn. §6~0-4-208(¥) - (g),
the Board hereby notifies all pa,rties in interest that· they pav¢ the right to seek judiCial
r~view of this final Board Order in this formal adjudication by :filing; ~th:riely appeal with
the Utah SuPreme Court within 30 days after the date thatthis Order issued. Utah Code
Ann. §§6~G-4~40H3)(a) and 403; As an ~Itern~tive to seeking iiUtlleqiate judicial
review, ancl n()t as (l prerequi§ite to seek;ingjudicial review, the Board. also h¢reby notifies
parties that they inay elect to r~ql!eSt that the J3q~rd recOJ)Sider this Order, wh!cll
constitutes a final agency action of th¢ Board. Ut£111 Gocte Ant;1, §63G-4.,.302, entitled,
"Agency Review -RecorisiderMiori/' states:
(1 )(a) Within 20 days. a~er tpe date that an order is issued for whiGh i'¢yiew by the agency or· by a slip¥ri6r agency U11Qet Sectio11 63G~4~30 1 is unavailable, and ifthe ()nl~r would othyrnrise cqnstitute final ageilcy actiqn, <my party may file a writte111'equesf for reconsid~ratfop wit~ the · ~gency, stating the spycific grounds upqti which relief is requested.
(b) l]nless otherwise provided by statute; th~ filing ofthe request is not a prerequisite for seekingjuqicial review of the order:
(2) The request for recopsideration shall be filed with the agency a11d one copy shall be sent by mail to each party by the person, tnilking the request.
(3)(a) The agency head, or a person designated for that purpose, shall issue a written order granting the req11est or denyitig the request.
(b) If the agency head or the person designated for that purpose does not issue an order within 20 days after the filing of the request, the request for reconsideration shall be considered to be denied.
9
!d. The Boarp also hereby notifies the parties that Utah Adtnin. Code Rule R,_641-11 0-
1 oo, which is part of a group of Bo(;lrd rulet) en.titled, "Rehearing and Modific~:ttion of
Existing Orders," states:
Any person affected by .. !!. fjnal. order ()r .·decision of the Boatd may. ?Ie a petiti()n f~r rehearing .. Unless qtherwise pr()vide?~ a petition for rehearing must be fi,le<i no Iat¢fthan the 1Oth day ofthe lllonth following the d!;lte of signing qf the fin~1 or4er. pr decision for Whi~4 the reh~ariilg is sought~. A copy qf sllch pf(titfo11 will be served on e&:ch othet party t() the Pl'oceeding no Iat~rthan the Bth qay 9fthe 1llonth. · . · · ..
!d. See Utah Admin. Cqde Rule R641~11Q-:-200 fqr the required contents of a petition for
Rehearing. If there is any conflict between the deaqlirie in Utah Code Ann, §63 G-4-3 02
and the deadline in Ptah Admin. Code Rule R641 -:-11 o~ 1 00 for moving to rehear this
matter, the Board hereby rules that the later ofthe tWq deadlines shalf be available to any
party 111oving to rehear this 111atter. If the Board later deriies a till1ely petition for
rehearing, the party may still seek judicial review of the Order by perfecting a timely
appe!;ll with the Utah Supreme Cotitt within30 days thereafter.
6. The Bqard retains continuing jurisdiction over all the parties and over the
subject matter of this Cause, except to the extent said jurisdiction l11ay be divested by the
filing of a timely appeal to seekjudicial review of this order by the Utah Supreme Court.
For all purposes, the Chairman's signature on a faxed copy of this Order shall be
deemed the equivalent of a signed original.
10
DATED this 18th day ofDecember, 2014.
STATE OFU'fAH BOARD OF OIL, GAS AND MINING
Hi50.02
11
EXHIBIT C
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EXHIBIT C _; L
EXHIBITD
STATE OF UTAH DEPARTMENT OF NATURAL RESOURCES
DIVISION OF OIL, GAS AND MINING
WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. TYPE OF WELL: OIL IZ] GAS D DRY D OTHER WELL WELL
b. TYPE OF WORK: NEW IZI WELL
HORIZ. D LATS.
DEEP- 0 EN
RE- D ENTRY
DIFF. D RESVR, OTHER
2. NAME OF OPERATOR:
Fidelity Exploration and Production Co
3. ADDRESS OF OPERATOR: I PHONE NUMBER:
1801 California St. Ste 41 cnY Denver STATE CQ ZIP80202 {303) 893-3133
4. lOCATIONOFWELL{fOOTAGES)
AT SURFACE: 858 FWL 1114 FSL
AT TOP PRODUCING INTERVAL REPORTED BELOW: 6576 FWL 1539 FSL
AT TOTAL DEPTH: 861 FNL 897 FEL
AMENDED REPORT 0 (highlight changes)
FORMS
5, LEASE DESIGNATION AND SERIAL NUMBER:
ML-43565
6. IF INDIAN, ALLOTTEE OR TRIBE NAME
7. UNIT orCA AGREEMENT NAME
Cane Creek
B. WELL NAME and NUMBER:
Cane Creek Unit 32-1-25-19
9. API NUMBER:
4301950037
10 FIELD AND POOL, OR WILDCAT
Cane Creek
11. 2I~gJft-J:SECTION, TOWNSHIP, RANGE,
swsw 32 25S 19E s
12. COUNTY 113. STATE
Grand UTAH
14. DATE SPUDDED: 1164/4/201·:EACHED:
116. DATE COMPLETED: ABANDONEDD READY TO PRODUCE IZ]
17. ELEVATIONS (DF, RKB, RT, GL):
2/12/2014 5/2/2014 5663 GL
18. TOTAL DEPTH: MD 12,025 ' r9. PLUG BACK T.D.: MD . ·120. IF MULTIPLE COMPLETIONS, HOW MANY? • 21. DEPTH BRIDGE MD PLUG SET:
TVD 7,562 TVD TVD
22. TYPE ELECTRIC AND OTHER MECHANICAL LOGS RUN (Submit copy of each) 23.
WAS WELL CORED? NoiZ] YESD (Submll analysis)
WASDSTRUN? No!£] YesO (Submit report)
DIRECTIONAL SURVEY? NOD YESIZ] (Submit copy)
24. CASING AND LINER RECORD (Report all strings sot in well)
HOLE SIZE SIZE/GRADE WEIGHT (#/ft.) TOP{MD) llOTTOM{MD) STAGE CEMENTER CEMENTTYPE & SLURRY CEMENT TOP .. AMOUNT PULLED DEPTH NO. OF SACKS VOLUME (BilL)
26 20 0 110 15yds 0
17 1/2 13 3/8 J55 54.5 0 1,201 B 935 428 0
12 1/4 9 5/8 HC~ 47 0 4,459 B 740 276 0
81/2 7 HC~ 29 0 4,393
81/2 7 HCJiJ: 32 4,393 8,136
8/12 7 HC~ 29 8,136 12,019 B 930 266 5750
26. TUBING RECORD
SIZE I DEPTH SET {MD) I PACKER SET {MD) I SIZE DEPTH SET (MD) I PACKER SET (MD) I SIZE I DEPTH SET (MD) I PACKER SET (MD)
I I I I I I I 26. PRODUCING INTERVALS 27. PERFORATION RECORD
FORMATION NAME TOP(MD) BOTTOM(MD) TOP (TVD) BOTTOM (TVD) INTERVAL (Top/Bot- MD) SIZE NO. HOLES PERFORATION STATUS
(A) Cane Creek 7,800 11.925
(B)
(C)
(D)
2ij, ACID, FRACTURE, TREATMENT, CEMENT SQUEEZE, ETC.
WAS WELL HYDRAULICALLY FRACTURED?
DEPTH INTERVAL
29, ENCLOSED ATTACHMENTS:
D ELECTRICAUMECHANICAL LOGS
D SUNDRY NOTICE FOR PLUGGING AND CEMENT VERIFICATION
(5/2013)
7,800 8,580 .35 3,900 Open llJ Squeezed D
8,660 9,080 .35 2,100 Open llJ Squeezed 0 9,160 10,200 .35 5,200 Open llJ Squeezed 0 10,240 11,060 .35 4,100 Open IZJ Squeezed 0
IF YES -DATE FRACTURED:
AMOUNT AND TYPE OF MATERIAL
30. WELL STATUS:
D GEOLOGIC REPORT
D COREANALYSIS
0 DST REPORT [;Zj DIRECTIONAL SURVEY Producing D OTHER: ________ _
(CONTINUED ON BACK)
31. INITIAL PRODUCTION INTERVAL A (As shown In Item #26)
DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL- BBL: GAS-MCF: WATER-BBL: PROD. METHOD:
5/5/2014 5/5/2014 24 RATES: -t 181 182 FlowlnQ
CHOKE SIZE: ITBG. PRESS. CSG.PRESS. I API GRAVITY BTU-GAS IGASIOIL RATIO 24 HR PRODUCTION OIL-BBL: GAS-MCF: WATt::R-BBL: INTERVAL STATUS:
4/64 852 552 RATES: -t
INTERVAL B (As shown in Item #26)
DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL-BBL: GAS-MCF: WATER-BBL: PROD. METHOD: RATES: -+
CHOKE SIZE: rBG.PRt::SS. CSG. PRESS. I API GRAVITY BTU-GAS I GAS/OIL RATIO 24 HR PRODUCTION OIL-BBL: GAS-MCF: WATER-BBL: INTERVAL STATUS: RATES: -+
INTERVAL C (As shown In item #26)
DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL-BBL: GAS-MCF: WATER-BBL: PROD. METHOD: RATES: -+
CHOKE SIZE: rBG.PRESS. CSG.PRESS. I API GRAVITY BTU-GAS . IGAS/OILRATIO 24 HR PRODUCTION OIL-BBL: GAS-MCF: WATER-BBL: INTERVAL STATUS: RATES: -t
INn;RVAL D (AS shown In item #26)
DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION Oll-BBL: GAS-MCF: WATER-BBL: PROD. METHOD: RATES: -t
CHOKE SIZE: ITBG. PRESS. CSG.PRESS. I API GRAVITY BTU-GAS IGAS/O!L RATIO 24 HR PRODUCTION Oll-BBL: GAS-MCF: WATER-BBL: INTERVAL STATUS: RATES: -+
32. DISPOSITION OF GAS (Sold, Used for Fuel, Vented, Etc.)
Vented
33. SUMMARY OF POROUS ZONES (Include Aquifers}: 34. FORMATION (Log) MARKERS:
Show all Important zones of porosity and conlenls thereof: Cored Intervals and all drill-stem tests, Including depth Interval tested, cushion used, time tool open, flowing and shut-in pressures and recovenes.
FormaUon Top Bottom Descriplions, Contents, etc. Name Top {MD) {MD) {Measured Depth)
Clastic 12 6,007 6,059 Moenkopi 1.403 Clastic 18 7,128 7,194 Cutler 1.822 Cane Creek 7,475 7,582 Honaker Trail 3,017
Paradox 4,077
35. ADDITIONAL REMARKS (Include pluggmg procedure)
36. I hereby certify that the foregoing and attached information is complete and correct as determined from all available records.
NAME(PLEASE PRINT)....:S:...:a:::n.:..:d:::i....:S:...t:...:O....:C.:..:k.:..:e:::r -------------- TITLE Engineerin!.] Tech
SIGNATURE DATE 8/20/2014
This report must be submitted within 30 days of • completing or plugging a new well o reentering a previously plugged and abandoned well • drilling horizontal laterals from an existing well bore • recompleting to a different producing formation
• significantly deepening an existing well bore below the previous bottom-hole depth o drilling hydrocarbon exploratory holes, such as core samples and stratigraphic tests
* ITEM 20: Show the number of completions If production is measured separately from two or more formations.
**ITEM 24: Cement Top- Show how reported top(s) of cement were determined (circulated (CIR), calculated (CAL), cement bond log (CBL), temperature survey (TS)).
Send to:
(5/2013)
Utah Division of Oil, Gas and Mining 1594 West North Temple, Suite 1210 Box 145801 Salt Lake City. Utah 84114-5801
Phone: 801-538-5340
Fax: 801-359-3940
EXHIBITE
PROJECT NO. : COMPANY NAME : ACCOUNT NO. :
365 S. MAIN ST. BRIGHTON, CO
80601 ~
303-637-0150
EXTENDED NATURAL GAS ANALYSIS (*DHA)
MAIN PAGE
201407154 ANALYSIS NO. : FIDELITY EXPLORATION ANALYSIS DATE:
SAMPLE DATE : CYLINDER NO. :
03 AUGUST 1, 2014 JULY 28, 2014 1373 PRODUCER
LEASE NO. : SAMPLED BY : GALE MCENDREE - EMPACT NAME/DESCRIP : PRODUCED TREATER GAS 10:20
CANE CREEK UNIT 32-1-25-19 ***FIELD DATA*** SAMPLE PRES. :
SAMPLE TEMP. : 121 35 AMBIENT TEMP.:
VAPOR PRES. : GRAVITY COMMENTS SPOT; NO PROBE; LENGTH OF H2S STAIN@ OPPM (1-7PPM) 10:25
GPM@ COMPONENT MOLE% MASS% ALCOHOLS 0.0009 0.0024 HELIUM 0.02 0.00 HYDROGEN 0.00 0.00 OXYGEN/ARGON 0.01 0.01 NITROGEN 0.94 0.96 CARBON DIOXIDE 0.01 0.02 METHANE 56.51420 33.16270 ETHANE 19.4609 21.4048 PROPANE 13.7729 22.2152 I-BUTANE 1.6501 3.5082 N-BUTANE 4.4065 9.3684 I-PENTANE 0.8843 2.3308 N-PENTANE 1.1517 3.0395 HEXANES PLUS 1.1785 3.9780
TOTALS 100.00000 100.00000
BTEX COMPONENTS MOLE% WT% BTU@ BENZENE 0.0287 0.0820 LOW NET DRY REAL : TOLUENE 0.0185 0.0624 NET WET REAL: ETHYLBENZENE 0.0015 0.0058 HIGH GROSS DRY REAL : XYLENES 0.0058 0.0226 GROSS WET REAL :
TOTAL BTEX 0.0545 0.1728 NET DRY REAL : GROSS DRY REAL :
RELATIVE DENSITY (AIR=1): (CALC: GPA STD 2145 & TP-1 7 @14.696 & 60 F) COMPRESSIBILITY FACTOR *(DETAILED HYDROCARBON ANAL)'SISINJ 1993); ASTM D6730
THIS DATA HAS BEEN ACQUIRED THROUGH APPLICATION OF CURRENT STATE-OF-THE-ART ANAL>TICAL TECHNIQUES.
THE USE OF THIS INFORMATION IS THE RESPONSIBL/TY OF THE USER. EMPACT ANALlTICAL SYSTEMS, ASSUMES NO
RESPONSIBL/TY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION.
EXHIBITE
14.650
5.2063 3.7962 0.5406 1.3901 0.3209 0.4172 0.4821
12.1534
14.650 1463.3 /scf 1437.7 /scf 1602.7 /scf 1574.7 /scf
20334 .9 flb 22276.9 flb
GPM@ 14.730
5.2347 3.8169 0.5435 1.3977 0.3227 0.4195 0.4846
12.2196
14.730 1471.3 /scf 1445.7 /scf 1611.5 /scf 1583.4 /scf
20445.9 /lb 22398.5 /lb
0.9427 0.99394
PROJECT NO. : COMPANY NAME : ACCOUNT NO. : PRODUCER LEASE NO. : NAME/DESCRIP :
365 S. MAIN ST. BRIGHTON, CO
80601 ~
303-637-0150
EXTENDED NATURAL GAS ANALYSIS (*DHA)
GLYCALC INFORMATION
201407154 FIDELITY EXPLORATION
PRODUCED TREATER GAS 10:20 CANE CREEK UNIT 32-1-25-19
ANALYSIS NO. : ANALYSIS DATE: SAMPLE DATE : CYLINDER NO. : SAMPLED BY :
03 AUGUST 1, 2014 JULY 28, 2014 1373 GALE MCENDREE - EMPACT
***FIELD DATA*** SAMPLE PRES. :
SAMPLE TEMP.: 121
VAPOR PRES. : COMMENTS
Componet Helium Hydrogen Carbon Dioxide Nitrogen Methane Ethane Propane lsobutane n-Butane lsopentane n-Pentane Cyclopentane n-Hexane Cyclohexane Other Hexanes Heptanes Methycyclohexane 2,2,4 Trimethylpentane Benzene Toluene Ethyl benzene Xylenes C8+ Heavies Subtotal Oxygen/Argon Alcohols
Total
35 AMBIENT TEMP.: GRAVITY
SPOT; NO PROBE; LENGTH OF H2S STAIN@ OPPM (1-7PPM) 10:25
Mole% Wt% 0.02 0.00 0.00 0.00 0.01 0.02 0.94 0.96
56.51420 33.16270 19.4609 21.4048 13.7729 22.2152
1.6501 3.5082 4.4065 9.3684 0.8436 2.2264 1.1517 3.0395 0.0407 0.1044 0.3066 0.9664 0.0806 0.2481 0.3756 1.1787 0.1948 0.7118 0.0462 0.1659 0.0005 0.0021 0.0287 0.0820 0.0185 0.0624 0.0015 0.0058 0.0058 0.0226 0.1197 0.5322
99.98910 99.98760 0.01 0.01
0.0009 0.0024
100.00000 100.00000
THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT
STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE
RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS, INC. ASSUMES NO RESPONSIBILITY
FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION.
EXTENDED NATURAL GAS ANALYSIS (*DHA}
DHA COMPONENT LIST
PROJECT NO. : 201407154 ANALYSIS NO.: 03 COMPANY NAME: FIDELITY EXPLORATION ANALYSIS DATE: AUGUST 1, 2014 ACCOUNT NO. : SAMPLE DATE : JULY 28, 2014 PRODUCER CYLINDER NO. : 1373 LEASE NO. : SAMPLED BY : GALE MCENDREE- EMPACT NAME/DESCRlP : PRODUCED TREATER GAS I 0:20
CANE CREEK UNIT 32-1-25-19 ***FIELD DATA*** SAMPLE TEMP. : 121 SAMPLE PRES. : 35 AMBIENT TEMP.: VAPOR PRES. GRAVITY COMMENTS SPOT; NO PROBE; LENGTH OF H2S STAIN@ OPPM (l-7PPM) 10:25
GPM@ GPM@
COMPONENT PIANO# MOLE% MASS% 14.650 14.730
Helium 0.02 0.00
Hydrogen 0.00 0.00
Oxygen/ Argon 0.01 0.01
Nitrogen 0.94 0.96
Carbon Dioxide 0.01 0.02
Methane PI 56.51420 33.16270
Ethane P2 19.4609 21.4048 5.206 5.235
Propane P3 13.7729 22.2152 3.796 3.817
i-Butane 14 1.6501 3.5082 0.541 0.544
n-Butane P4 4.4063 9.3680 1.390 1.398
2,2-Dimethylpropane I5 0.0081 0.0214 0.003 0.003
i-Pentane I5 0.8355 2.2050 0.306 0.308
i-Propanol X3 0.0001 0.0002 0.000 0.000
UnknownC4s U4 0.0002 0.0004 0.000 0.000
n-Pentane P5 1.1510 3.0376 0.417 0.420
!-Butanol X4 0.0006 0.0016 0.000 0.000
2,2-Dimethylbutane 16 0.0059 0.0186 0.002 0.002
Cyclopentane N5 0.0407 0.1044 0.012 0.012
2,3-Dimethylbutane I6 0.0220 0.0694 0.009 0.009
2-Methylpentane I6 0.1840 0.5800 0.076 0.077
i-Butanol X4 0.0002 0.0006 0.000 0.000
3-Methylpentane I6 0.0930 0.2931 0.038 0.038
UnknownC5s us 0.0007 0.0019 0.000 0.000
n-Hexane P6 0.3066 0.9664 0.126 0.127
2,2-Dimethylpentane I7 0.0002 0.0007 0.000 0.000
Methylcyclopentane N6 0.0705 0.2170 0.025 0.025
2,4-Dimethylpentane 17 0.0056 0.0205 0.003 0.003
2,2,3-Trimethy I butane 17 0.0004 0.0015 0.000 0.000
Benzene A6 0.0287 0.0820 0.008 0.008
3,3-Dimethylpentane 17 0.0006 0.0022 0.000 0.000
Cyclohexane N6 0.0806 0.2481 0.027 0.027
2-Methylhexane 17 0.0278 0.1019 0.013 0.013
2,3-Dimethylpentane 17 0.0098 0.0359 0.004 0.004
I, 1-Dimethylcyclopentane N7 0.0055 0.0198 0.002 0.002
3-Methylhexane 17 0.0304 0.1114 0.014 0.014
1 c,3-Dimethylcyclopentane N7 0.0067 0.0241 0.003 0.003
1 t,3-Dimethylcyclopentane N7 0.0060 0.0215 0.003 0.003
3-Ethylpentane 17 0.0013 0.0048 0.001 0.001
I t,2-Dimethylcyclopentane N7 0.0095 0.0341 0.004 0.004
2,2 ,4-Trimethylpentane 18 0.0005 0.0021 0.000 0.000
UnknownC6s U6 0.0002 0.0006 0.000 0.000
Page 1
EM PACT Analytical Systems, Inc 365 S. Main Street, Brighton, CO 80601 303·637-0150
n-Heptane
I c,2-Dimethylcyclopentane
Methylcyclohexane
2,2-Dimethylhexane
Ethylcyclopentane
2,5-Dimethy1hexane
2,2,3-Trimethylpentane
2,4-Dimethy1hexane
I c,2t,4-Trimethylcyclopentane
3,3-Dimethy1hexane
I t,2c,4-Trimethylcyclopentane
2,3 ,4-Trimethylpentane
Toluene
2,3-Dimethy1hexane
2-Methy1-3-ethylpentane
I, I ,2-Trimethylcyclopentane
2-Methylheptane
4-Methylheptane
3-Methyl-3-ethylpentane
3,4-Dimethylhexane
I c,2c,4-Trimethylcyclopentane
I c,3-Dimethylcyclohexane
3-Methylheptane
I c,2t,3-Trimethylcyclopentane
3-Ethylhexane
I 1,4-Dimethylcyclohexane
I, I -Dimethylcyclohexane
3c-Ethylmethylcyclopentane
3t-Ethylmethylcyclopentane
2t-Ethylmethylcyclopentane
I, 1-Methylethylcyclopentane
2,2,4-Trimethylhexane
I t,2-Dimethy1cyclohexane
UnknownC7s
n-Octane
I c,4-Dimethylcyclohexane
i-Propy1cyclopentane
2,4,4-Trimethylhexane
2,3,5-Trimethy1hexane
2,2,3,4-Tetramethylpentane
2,3,4-Trimethylhexane
1c,2-Dimethy1cyclohexane
I, I ,4-Trimethylcyclohexane
2,2,3-Trimethylhexane
2,4-Dimethylheptane
4,4-Dimethy1heptane
Ethylcyclohexane
n-Propylcyclopentane
I c,3c,5-Trimethylcyc1ohexane
2,5-Dimethylheptane
3,3-Dimethylheptane
3,5-Dimethy1heptane
I, I ,3-Trimethylcyclohexane
Ethylbenzene
I c,2t,4t-Trimethylcyclohexane
2,3-Dimethy1heptane
1 ,3-Dimethy1benzene (m-Xylene)
1,4-Dimethylbenzene (p-Xy1ene)
3,4-Dimethy1heptane
3,4-Dimethylheptane (2)
4-Ethylheptane
4-Methy1octane
2-Methyloctane
3-Ethy1heptane
EMPACT Analytical Systems, Inc
P7
N7
N7
18 N7
18 18
18 NS 18
N8 18 A7 18
18 N8 18
18 18
18 N8 N8 18
N8 18 N8 N8 N8 N8 N8 N8 19
N8 U7
P8
NS 18 19
19
19
19
N8 N9
19
19
19
NS NS N9
19
19
I9 N9
18 N9
19
A8
AS 19
19
19
19
19
19
0.0880
0.0008
0.0462
0.0029
0.0016
0.0010
0.0006
0.0024
0.0018
0.0007
0.0014
0.0001
0.0185
0.0019
0.0007
0.0001
0.0119
0.0026
0.0005
0.0007
0.0001
0.0001
0.0055
0.0061
0.0011
0.0024
0.0008
0.0001
0.0003
0.0002
0.0005
0.0001
0.0023
0.0006
0.0208
0.0036
0.0001
0.0001
0.0001
0.0001
0.0002
0.0006
0.0033
0.0019
0.0001
0.0001
0.0017
0.0012
0.0002
0.0001
0.0001
0.0001
0.0001
0.0015
0.0006
0.0003
0.0029
0.0014
0.0002
0.0002
0.0002
0.0009
0.0014
0.0003
Page 2
0.3226
0.0029
0.1659
0.0121
0.0057
0.0042
0.0025
0.0100
0.0074
0.0029
0.0057
0.0004
0.0624
0.0079
0.0029
0.0004
0.0497
0.0109
0.0021
0.0029
0.0004
0.0004
0.0230
0.0250
0.0046
0.0098
0.0033
0.0004
0.0012
0.0008
0.0021
0.0005
0.0094
0.0022
0.0869
0.0148
0.0004
0.0005
0.0005
0.0005
0.0010
0.0025
0.0153
0.0089
0.0005
0.0005
0.0070
0.0049
0.0009
0.0005
0.0005
0.0005
0.0005
0.0058
0.0028
0.0014
0.0113
0.0055
0.0010
0.0010
0.0010
0.0042
0.0066
0.0014
365 S. Main Street, Brighton, CO 80601
0.040
0.000
0.019
0.001
0.001
0.001
0.000
0.001
0.001
0.000
0.001
0.000
0.006
0.001
0.000
0.000
0.006
0.001
0.000
0.000
0.000
0.000
0.003
0.003
0.001
0.001
0.000
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.011
0.002
0.000
0.000
0.000
0.000
0.000
0.000
0.002
0.001
0.000
0.000
0.001
0.001
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.000
0.001
0.001
0.000
0.000
0.000
0.001
0.001
0.000
0.040
0.000
0.019
0.001
0.001
0.001
0.000
0.001
0.001
0.000
0.001
0.000
0.006
0.001
0.000
0.000
0.006
0.001
0.000
0.000
0.000
0.000
0.003
0.003
0.001
0.001
0.000
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.011
0.002
0.000
0.000
0.000
0.000
0.000
0.000
0.002
0.001
0.000
0.000
0.001
0.001
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.000
0.001
0.001
0.000
0.000
0.000
0.001
0.001
0.000
303-637-0150
3-Methyloctane
I c,2t,4c-Trimethylcyclohexane
I, I ,2-Trimethylcyclohexane
3,3-Diethylpentane
I ,2-Dimethylbenzene (o-X ylene)
i-Butylcyclopentane
UnknownC8s
n-Nonane
I, 1-Methylethylcyclohexane
i-Propylbenzene
i-Propylcyclohexane
2,2-Dimethyloctane
2,4-Dimethyloctane
2,5-Dimethyloctane
n-Butylcyclopentane
3,3-Dimethyloctane n-Propylbenzene
3,6-Dimethyloctane
3-Methyl-5-ethylheptane
I ,3-Methylethylbenzene
I ,4-Methylethylbenzene
I ,3,5-Trimethylbenzene
2,3-Dimethyloctane
5-Methylnonane
I ,2-Methylethylbenzene
3-Ethyloctane
3-Methylnonane
t-Butylbenzene
i-Butylcyclohexane
i-Butylbenzene
UnknownC9s
n-Decane
1 ,2,3-Trimethylbenzene
1,3-Methyl-i-propylbenzene
Sec-Butylcyclohexane
I ,2-Methyl-i-propylbenzene
1 ,3-Diethylbenzene
1 ,3-Methyl-n-propylbenzene
I ,4-Diethylbenzene
I ,3-Dimethyl-5-ethylbenzene
I ,2-Diethylbenzene
t-Decahydronaphthalene
I ,2-Methyl-n-propylbenzene
I ,4-Dimethyl-2-ethylbenzene
1 ,2-Dimethyl-4-ethylbenzene
1 ,3-Dimethyl-2-ethylbenzene
I ,2-Dimethyl-3-ethylbenzene
I ,4-Methyl-t-butylbenzene
UnknownC!Os
n-Undecane
I ,4-Ethyl-i -propylbenzene
I ,2,4,5-Tetramethylbenzene
I ,2-Methyl-n-butylbenzene
1,2,3,5-Tetramethylbenzene
I ,2-Methyl-t-butylbenzene
1 ,2-Ethyl-n-propylbenzene
I ,3-Methyl-n-butylbenzene
I ,3-Di-i-propylbenzene
sec-Pentylbenzene
n-Pentylbenzene
1 ,4-Di-i-propylbenzene
Naphthalene
UnknownC!ls
n-Dodecane
EMPACT Analytical Systems. Inc
!9
!9
N9
19 A8 N9
U8
P9
N9
A9
N9 !10
!10 !10 N9
110 A9 !10 110
A9 A9 A9 !10
!10 A9
110 110 A10 N10
AIO U9
PIO
A9 A10
AIO AIO
A10 A10 AIO AIO A10
A9 AIO AIO A10 A10
AIO All UIO Pll All
All All All All All All
All All All All
AIO Ull
P12
0.0016 0.0001
0.0001 0.0001 0.0015 0.0007 0.0002 0.0067 0.0004 0.0003 0.0002 0.0001 0.0002 0.0001 0.0008 0.0002
0.0008 0.0003 0.0004 0.0004 0.0001
0.0004 0.0001 0.0004 0.0005 0.0001
0.0004 0.0010 0.0002
0.0001 0.0021
0.0027 0.0003 0.0001
0.0003 0.0002
0.0001 0.0001 0.0002 0.0001
0.0001 0.0001 0.0001 0.0001
0.0002 0.0001 0.0001 0.0001 0.0020
0.0013 0.0001 0.0001 0.0001 0.0001 0.0001
0.0001 0.0001 0.0001 0.0001
0.0001 0.0001 0.0001
0.0009 0.0006
Page3
0.0075 0.0005 0.0005 0.0005
0.0058 0.0032
0.0008 0.0314
0.0018 0.0013 0.0009 0.0005 0.0010 0.0005 0.0037 0.0010 0.0035 0.0016 0.0021
0.0018 0.0004 0.0018 0.0005
0.0021 0.0022 0.0005 0.0021
0.0049 0.0010 0.0005 0.0098 0.0141
0.0013 0.0005 0.0015 0.0010
0.0005 0.0005 0.0010 0.0005
0.0005 0.0006 0.0005 0.0005
0.0010 0.0005 0.0005 0.0006 0.0104 0.0074
0.0006 0.0005 0.0006 0.0005 0.0006
0.0006 0.0006 0.0006 0.0006
0.0006 0.0006 0.0005 0.0052
0.0037
365 S. Main Street, Brighton, CO 80601
0.001
0.000 0.000 0.000 0.001 0.000 0.000 0.004 0.000 0.000
0.000 0.000
0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.001 0.002
0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000 0.001
0.001 0.000 0.000 0.000
0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.001
0.000
0.001 0.000 0.000 0.000
0.001 0.000 0.000 0.004 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.001 0.002
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000 0.001 0.001 0.000
0.000 0.000 0.000 0.000 0.000 0.000
0.000 0.000 0.000 0.000
0.000 0.001 0.000
303-637-0150
I ,2,4-Triethylbenzene Al2 I ,2,3,4,5-Pentamethylbenzene A13
UnknownC12s Ul2 n-Tridecane P13
UnknownC13s Ul3 n-Tetradecane Pl4 UnknownC14s Ul4 n-Pentadecane PIS UnknownCISs UIS
TOTAL
BTEX COMPONENTS BENZENE
MOLE% WT%
TOLUENE ETHYLBENZENE XYLENES TOTAL BTEX
0.0287 0.0820 0.0185 0.0624 0.0015 0.0058 0.0058 0.0226 0.0545 0.1728
0.0001 0.0006 0.000
0.0001 0.0006 0.000
0.0007 0.0040 0.000
0.0003 0.0020 0.000
0.0004 0.0027 0.000 0.0001 0.0007 0.000
0.0002 0.0015 0.000
0.0001 0.0008 0.000
0.0001 0.0008 0.000
100.00000 100.00000 12.1534
BTU@ 14.650 LOW NET DRY REAL : 1463.3 /scf
NET WET REAL : 1437.7 /scf IDGH GROSS DRY REAL : 1602.7 /scf
GROSS WET REAL : 1574.7 /scf NET DRY REAL : 20334.9/lb GROSS DRY REAL : 22276.9/lb
RELATIVE DENSITY (AIR=1): (CALC: GPA STD2145 & [email protected] &60 F) COMPRESSIBILITY FACTOR : '(DETAILED HYDROCARBON ANALYSIS!NJ 1993); ASTM D6730
THIS DATA liAS BEEN ACQUIRED THROUGH APPLICATION OF CURRENT STATE-OF-THE-ART ANALlTICAL TECHNIQUES.
THE USE OF TillS INFORMATION IS THE RESPONSIBL/Tl' OF TilE USER. EMPACT ANALlTICAL SYSTEMS, ASSUMES NO
RESPONSIBLITY FOR ACCURACY OF TilE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION.
Page4
EMPACT Analytical Systems, Inc 365 S. Main Street, Brighton, CO 80601
0.000
0.000
0.000 0.000
0.000 0.000
0.000
0.000 0.000
12.2196
14.730 1471.3 /scf 1445.7 /scf 1611.5/scf 1583.4 /scf
20445.9/lb 22398.5/lb
0.9427 0.99394
303-637-0150
PROJECT NO. : COMPANY NAME : ACCOUNT NO. :
365 S. MAIN ST. BRIGHTON, CO
80601 ~
303-637-0150
EXTENDED NATURAL GAS ANALYSIS (*DHAl
MAIN PAGE
201407154 ANALYSIS NO. : FIDELITY EXPLORATION ANALYSIS DATE:
SAMPLE DATE : CYLINDER NO. :
04 AUGUST 3, 2014 JULY 28, 2014 0320 PRODUCER
LEASE NO. : SAMPLED BY : GALE MCENDREE- EMPACT NAME/DESCRIP : PRE COMBUSTOR TANK GAS 10:35
CANE CREEK UNIT 32-1-25-19 ***FIELD DATA*** SAMPLE PRES. : VAPOR PRES. : COMMENTS
COMPONENT ALCOHOLS HELIUM HYDROGEN OXYGEN/ARGON NITROGEN CARBON DIOXIDE METHANE ETHANE PROPANE I-BUTANE N-BUTANE I-PENTANE N-PENTANE HEXANES PLUS
TOTALS
BTEX COMPONENTS BENZENE TOLUENE ETHYLBENZENE XYLENES
TOTAL BTEX
>1#
SPOT; NO PROBE
MOLE% WT% 0.0771 0.1585 0.0486 0.1179 0.0049 0.0137 0.0179 0.0500 0.1485 0.3401
(CALC: GPA STD 2145 & TP-Il @I4.696 & 60 F)
*(DETAILED HYDROCARBON ANALYSIS!NJ I993); ASTM D6730
MOLE% 0.0039
0.00 0.01 6.33
23.44 0.04
14.10370 15.8146 19.9377 3.0941 9.1679 2.1391 2.8550 3.0640
100.00000
SAMPLE TEMP. : AMBIENT TEMP.: GRAVITY
MASS% 0.0060
0.00 0.00 5.33
17.29 0.05
5.95670 12.5174 23.1423
4.7338 14.0264 4.0576 5.4221 7.4677
100.00000
BTU@ LOW NET DRY REAL :
NET WET REAL : HIGH GROSS DRY REAL :
GROSS WET REAL : NET DRY REAL : GROSS DRY REAL :
RELATIVE DENSITY {AIR=1): COMPRESSIBILITY FACTOR :
80
GPM@ 14.650
4.2395 5.5057 1.0149 2.8970 0.7777 1.0370 1.2755
16.7473
14.650 1548.8 /scf 1521.7 /scf 1684.7 /scf 1655.2 /scf
15495.8 lib 16851.7 lib
TillS DATA liAS BEEN ACQUIRED THROUGH APPLICATION OF CURRENT STATE-OF-THE-ART ANALYTICAL TECHNIQUES.
TilE USE OF TillS INFORMATION IS THE RESPONSIBLITYOF TilE USER. EMPACT ANALYTICAL SYSTEMS. ASSUMES NO
RESPONSIBLITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION.
GPM@ 14.730
4.2627 5.5357 1.0205 2.9129 0.7821 1.0427 1.2826
16.8392
14.730 1557.3 /scf 1530.2 /scf 1693.9 /scf 1664.4 /scf
15580.4 lib 16943.8 lib
1.3107 0.99204
PROJECT NO. : COMPANY NAME : ACCOUNT NO. : PRODUCER LEASE NO. : NAME/DESCRIP :
***FIELD DATA*** SAMPLE PRES. : VAPOR PRES. : COMMENTS
Componet Helium Hydrogen Carbon Dioxide Nitrogen Methane Ethane Propane lsobutane n-Butane lsopentane n-Pentane Cyclopentane n-Hexane Cyclohexane Other Hexanes Heptanes Methycyclohexane 2,2,4 Trimethylpentane Benzene Toluene Ethyl benzene Xylenes C8+ Heavies Subtotal Oxygen/Argon Alcohols
Total
365 S. MAIN ST. BRIGHTON, CO
80601 ~
303-637-0150
EXTENDED NATURAL GAS ANALYSIS {*DHA)
GL YCALC INFORMATION
201407154 ANALYSIS NO. : FIDELITY EXPLORATION ANALYSIS DATE:
SAMPLE DATE : CYLINDER NO. : SAMPLED BY :
PRE COMBUSTOR TANK GAS 10:35 CANE CREEK UNIT 32-1-25-19
SAMPLE TEMP.: >1# AMBIENT TEMP.:
GRAVITY SPOT; NO PROBE
Mole% Wt% 0.00 0.00 0.01 0.00 0.04 0.05
23.44 17.29 14.10370 5.95670
15.8146 12.5174 19.9377 23.1423
3.0941 4.7338 9.1679 14.0264 2.0451 3.8840 2.8550 5.4221 0.0940 0.1736 0.7794 1.7680 0.2012 0.4457 0.9726 2.1968 0.5015 1.3185 0.1187 0.3068 0.0003 0.0009 0.0771 0.1585 0.0486 0.1179 0.0049 0.0137 0.0179 0.0500 0.3418 1.0909
93.66610 94.66400
6.33 5.33 0.0039 0.0060
100.00000 100.00000
THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT
STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE
RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS, INC. ASSUMES NO RESPONSIBILITY
FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION.
04 AUGUST 3, 2014 JULY 28, 2014 0320 GALE MCENDREE - EMPACT
80
EXTENDED NATURAL GAS ANALYSIS (*DHA}
DHA COMPONENT LIST
PROJECT NO. : 20 1407 154 ANALYSIS NO. : 04 COMPANY NAME: FIDELITY EXPLORATION ANALYSIS DATE: AUGUST 3, 20 14 ACCOUNT NO. : SAMPLE DATE : JULY 28,20 14 PRODUCER CYLINDER NO. : 0320 LEASE NO. : SAMPLED BY : GALE MCENDREE- EMPACT NAME/DESCRIP : PRE COMBUSTOR TANK GAS 10:35
CANE CREEK UNIT 32-1-25-19 ***FIELD DATA*** SAMPLE TEMP. : 80 SAMPLE PRES. : > I# AMBIENT TEMP.: VAPOR PRES. GRAVITY COMMENTS SPOT; NO PROBE
GPM @ GPM@
COMPONENT PIANO# MOLE% MASS% 14.650 14.730
Helium 0.00 0.00
Hydrogen 0.01 0.00 Oxygen/Argon 6.33 5.33
Nitrogen 23.44 17.29
Carbon Dioxide 0.04 0.05
Methane PI 14.10370 5.95670 Ethane P2 15 .8 146 12.5174 4.240 4.263
Propane P3 19.9377 23.1423 5.506 5.536
i-Butane 14 3.0941 4.7338 1.015 1.021
n-Butane P4 9.1677 14.0261 2.897 2.913
2,2-Dimethylpropane 15 0.0182 0.0346 0.007 0.007
Ethanol X2 0.0017 0.0020 0.000 0.000
i-Pentane 15 2.0269 3.8494 0.743 0.747
Acetone X3 0.0004 0.0006 0.000 0.000
i-Propanol X3 0.0002 0.0003 0.000 0.000
UnknownC4s U4 0.0002 0.0003 0.000 0.000
n-Pentane PS 2.8544 5.4210 1.037 1.043
!-Butanol X4 0.0015 0.0029 0.001 0.001
2,2-Dimethylbutane 16 0.0154 0.0349 0.006 0.006
Cyclopentane NS 0.0940 0.1736 0.028 0.028
2,3-Dimethylbutane 16 0.0691 0.1568 0.028 0.028
2-Methylpentane 16 0.4713 1.0691 0.196 0.197
3-Methylpentane 16 0.2381 0.5401 0.098 0.098
UnknownCSs us 0.0006 0.0011 0.000 0.000
n-Hexane P6 0.7794 1.7680 0.322 0.323
2,2-Dimethylpentane 17 0.0059 0.0156 0.003 0.003
Methylcyclopentane N6 0.1783 0.3950 0.063 0.064
2,4-Dimethylpentane 17 0.0146 0.0385 0.007 0.007
2,2,3 -Trimethylbutane 17 0.0008 0.0021 0.000 0.000
n-Butanol X4 0.0001 0.0002 0.000 0.000
Benzene A6 0.0771 0.1585 0.022 0.022
3,3-Dimethylpentane 17 0.0024 0.0063 0.001 0.001
Cyclohexane N6 0.2012 0.4457 0.068 0.069
2-Methylhexane 17 0.0713 0.1881 0.033 0.033
2,3-Dimethylpentane 17 0.0260 0.0686 0.012 0.012
I, 1-Dimethylcyclopentane N7 0.0125 0.0323 0.005 0.005
3-Methylhexane 17 0.0767 0.2023 0.035 0.035
I c,3-Dimethylcyclopentane N7 0.0175 0.0452 0.008 0.008
I !,3-Dimethylcyclopentane N7 0.0156 0.0403 0.007 0.007
3-Ethylpentane 17 0.0022 0.0058 0.001 0.001
I !,2-Dimethylcyclopentane N7 0.0269 0.0695 0.012 0.012
2,2,4-Trimethylpentane 18 0.0003 0.0009 0.000 0.000
Page 1
EMPACT Analytical Systems, Inc 365 S. Main Street, Brighton, CO 80601 303-637-0150
UnknownC6s
n-Heptane
I c,2-Dimethylcyclopentane
Methylcyclohexane
2,2-Dimethylhexane
Ethylcyclopentane
2,5-Dimethylhexane
2,2,3-Trimethylpentane
2,4-Dimethylhexane
I c,2t,4-Trimethylcyclopentane
3,3-Dimethylhexane
I t,2c,4-Trimethylcyclopentane
2,3,4-Trimethylpentane
2,3,3-Trimethylpentane
Toluene
2,3-Dimethylhexane
2-Methyl-3-ethylpentane
2-Methylheptane
4-Methylheptane
3-Methyl-3-ethylpentane
3,4-Dimethylhexane
I c,2c,4-Trimethylcyclopentane
I c,3-Dimethylcyclohexane
3-Methylheptane
I c,2t,3-Trimethylcyclopentane
3-Ethylhexane
I t,4-Dimethylcyclohexane
I, 1-Dimethylcyclohexane
3c-Ethylmethylcyclopentane
3t-Ethylmethylcyclopentane
2t-Ethylmethylcyclopentane
I, 1-Methylethylcyclopentane
2,2,4-Trimethylhexane
I t,2-Dimethylcyclohexane
I t,3-Dimethylcyclohexane
UnknownC7s
n-Octane
I c,4-Dimethylcyclohexane
i-Propylcyclopentane
2,4,4-Trimethylhexane
2,3,5-Trimethylhexane
2,2,3,4-Tetramethylpentane
2,3,4-Trimethylhexane
I c,2-Dimethylcyclohexane
2,2-Dimethylheptane
I, I ,4-Trimethylcyclohexane
2,2,3-Trimethylhexane
2,4-Dimethylheptane
4,4-Dimethylheptane
Ethylcyclohexane
n-Propylcyclopentane
I c,3c,5-Trimethylcyclohexane
2,5-Dimethylheptane
3,3-Dimethylheptane
3,5-Dimethylheptane
2,6-Dimethylheptane
I, I ,3-Trimethylcyclohexane
Ethylbenzene
I c,2t,4t-Trimethylcyclohexane
2,3-Dimethylheptane
I ,3-Dimethylbenzene (m-Xylene)
I ,4-Dimethylbenzene (p-Xylene)
3,4-Dimethylheptane
3,4-Dimethylheptane (2)
4-Ethylheptane
EMPACT Analytical Systems, Inc
U6
P7
N7
N7
18
N7
18
18
18
N8 18
N8 18
18
A7 18
18
18
18
18
18
N8 N8 18
N8 18
N8 N8 N8 N8 N8 N8 19
N8 N8 U7
P8
N8 18
19
19
19
19
N8 19
N9
19
19
19
N8 N8 N9
19
19
19
19
N9
18
N9
19
AS A8
19
19
19
0.0004
0.2216
0.0024
0.1187
0.0074
0.0041
0.0039
0.0005
0.0060
0.0048
0.0016
0.0037
0.0002
0.0001
0.0486
0.0054
0.0015
0.0315
0.0074
0.0015
0.0014
0.0004
0.0002
0.0130
0.0183
0.0025
0.0063
0.0022
0.0003
0.0006
0.0005
0.0013
0.0003
0.0064
0.0001
0.0010
0.0575
0.0101
0.0004
0.0002
0.0005
0.0003
0.0005
0.0022
0.0002
0.0098
0.0057
0.0001
0.0003
0.0055
0.0034
0.0006
0.0002
0.0003
0.0001
0.0001
0.0005
0.0049
0.0014
0.0013
0.0107
0.0028
0.0004
0.0005
0.0006
Page 2
0.0009
0.5845
0.0062
0.3068
0.0222
0.0106
0.0117
0.0015
0.0180
0.0142
0.0048
0.0109
0.0006
0.0003
0.1179
0.0162
0.0045
0.0947
0.0222
0.0045
0.0042
0.0012
0.0006
0.0391
0.0540
0.0075
0.0186
0.0065
0.0009
0.0018
0.0015
0.0038
0.0010
0.0189
0.0003
0.0026
0.1729
0.0298
0.0012
0.0007
0.0017
0.0010
0.0017
0.0065
0.0007
0.0326
0.0192
0.0003
0.0010
0.0162
0.0101
0.0020
0.0007
0.0010
0.0003
0.0003
0.0017
0.0137
0.0047
0.0044
0.0299
0.0078
0.0013
0.0017
0.0020
365 S. Main Street, Brighton, CO 80601
0.000
0.103
0.001
0.048
0.003
0.002
0.002
0.000
0.003 0.002
0.001
0.002
0.000
0.000
0.016
0.003
0.001
0.016
0.004
0.001
0.001
0.000
0.000
0.007
0.009
0.001
0.003
0.001
0.000
0.000
0.000
0.001
0.000
0.003
0.000
0.000
0.029
0.005
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.005
0.003
0.000
0.000
0.002
0.002
0.000
0.000
0.000
0.000
0.000
0.000
0.002
0.001
0.001
0.004
0.001
0.000
0.000
0.000
0.000
0.103
0.001
0.049
0.003
0.002
0.002
0.000
0.003
0.002
0.001
0.002
0.000
0.000
0.016
0.003
0.001
0.016
0.004
0.001
0.001
0.000
0.000
0.007
0.009
0.001
0.003
0.001
0.000
0.000
0.000
0.001
0.000
0.003
0.000
0.000
0.029
0.005
0.000
0.000
0.000
0.000
0.000
0.001
0.000
0.005
0.003
0.000
0.000
0.002
0.002
0.000
0.000
0.000
0.000
0.000
0.000
0.002
0.001
0.001
0.004
0.001
0.000
0.000
0.000
303-637-0150
4-Methyloctane 2-Methyloctane
I c,2t,3-Trimethylcyclohexane
3-Ethylheptane
3-Methyloctane I c,2t,4c-Trimethylcyclohexane
I, I ,2-Trimethylcyclohexane 3,3-Diethylpentane
I ,2-Dimethylbenzene (o-Xylene) i-Butylcyclopentane
UnknownCSs
n-Nonane I, 1-Methylethylcyclohexane
i-Propylbenzene i-Propylcyclohexane
2,2-Dimethyloctane
2,4-Dimethyloctane
2,6-Dimethyloctane 2,5-Dimethyloctane
n-Butylcyclopentane 3,3-Dimethyloctane
n-Propylbenzene
3,6-Dimethyloctane
3-Methyl-5-ethylheptane I ,3-Methylethylbenzene
I ,4-Methylethylbenzene
I ,3 ,5-Trimethylbenzene
2,3-Dimethyloctane 5-Methylnonane
I ,2-Methylethylbenzene
2-Methylnonane
3-Ethyloctane 3-Methylnonane
I ,2,4-Trimethylbenzene
t-Butylbenzene
i-Butylcyclohexane I t-Methyl-2-n-propylcyclohexane
i-Butylbenzene
sec-Butylbenzene
UnknownC9s n-Decane
I ,2,3-Trimethylbenzene
I ,3-Methyl-i-propylbenzene
I ,4-Methyl-i-propylbenzene Sec-Butylcyclohexane
I ,2-Methyl-i-propylbenzene
3-Ethylnonane
I ,3-Diethylbenzene I ,3 -Methyl-n-propylbenzene
I ,4-Diethylbenzene
I ,4-Methyl-n-propylbenzene
n-Butylbenzene I ,3-Dimethyl-5-ethylbenzene
I ,2-Diethylbenzene t-Decahydronaphthalene
I ,2-Methyl-n-propylbenzene
I ,4-Dimethyl-2-ethylbenzene
I ,3-Dimethyl-4-ethylbenzene I ,2-Dimethyl-4-ethylbenzene
I ,3-Dimethyl-2-ethylbenzene
I ,2-Dimethyl-3-ethylbenzene
I ,2-Ethyl-i-propylbenzene
I ,4-Methyl-t-butylbenzene UnknownC!Os
n-Undecane
EMPACT Analytical Systems, Inc
19 19
N9 19
19 19
N9 19
AS
N9 us P9 N9
A9 N9 110
110
110 IIO N9 IIO A9 110 110 A9 A9 A9 110 IIO A9 110
110 110
A9 AIO NIO IIO AIO AIO U9 PIO A9
AIO AIO AIO
AIO 110
AIO AIO AIO AIO AIO AIO AIO A9
AIO AIO AIO AIO AIO AIO AIO All
UIO PI!
0.0031
0.0043 0.0002
0.0009
0.0052 0.0001
0.0002 0.0004
0.0044 0.0024
0.0004
0.0224 0.0022
0.0008 0.0005
0.0003 0.0007
0.0001 0.0002
0.0026 0.0002
0.0028
0.0009
0.0014 0.0014
0.0006 0.0009
0.0005 0.0014
0.0019
0.0002
0.0003 0.0012
0.0003 0.0033
0.0006 0.0001
0.0003 0.0003
0.0056
0.0097 0.0012
0.0003
0.0002 0.0012
0.0007
0.0001
0.0001 0.0001
0.0003
0.0003 0.0002
0.0003
0.0002 0.0002
0.0004
0.0004
0.0001 0.0006
0.0001 0.0002
0.0002
0.0004 0.0082
0.0039
Page 3
O.oi05 0.0145
0.0007 0.0030
0.0176
0.0003
0.0007 0.0013 0.0123
0.0080
0.0012
0.0756 0.0073 0.0025
0.0017
0.0011 0.0026
0.0004
0.0007
0.0086 0.0007
0.0089 0.0034
0.0052
0.0044
0.0019 0.0028
0.0019
0.0052
0.0060 0.0007
0.0011
0.0045
0.0009 0.0117
0.0022
0.0004
0.0010 0.0010
0.0189
0.0363
0.0038 0.0010
0.0007 0.0044
0.0025
0.0004
0.0003 0.0003
0.0010
0.0010
0.0007 0.0010
0.0007
0.0008 0.0014
0.0014
0.0003 0.0021
0.0003
0.0007
0.0008
0.0015 0.0307
0.0161
365 S. Main Street, Brighton, CO 80601
0.002 0.002
0.000 0.001
0.003
0.000
0.000 0.000 0.002
0.001
0.000
0.013 0.001
0.000 0.000
0.000
0.000 0.000
0.000
0.001 0.000
0.001 0.001
0.001
0.001
0.000 0.000
0.000 0.001
0.001
0.000
0.000 0.001
0.000 0.002
0.000 0.000
0.000 0.000
0.003 0.006
0.001 0.000
0.000
0.001
0.000 0.000
0.000
0.000
0.000 0.000
0.000 0.000
0.000
0.000
0.000 0.000
0.000 0.000
0.000
0.000
0.000
0.000
0.005
0.003
0.002 0.002
0.000 0.001
0.003
0.000
0.000 0.000 0.002
0.001
0.000
0.013 0.001
0.000 0.000
0.000 0.000
0.000
0.000 0.001
0.000
0.001 0.001
0.001
0.001
0.000 0.000
0.000
0.001
0.001 0.000
0.000
0.001
0.000 0.002
0.000
0.000
0.000 0.000
0.003
0.006
0.001 0.000
0.000 0.001
0.000 0.000
0.000
0.000 0.000
0.000
0.000 0.000
0.000
0.000
0.000 0.000
0.000 0.000
0.000
0.000
0.000
0.000
0.005
0.003
303-637-0150
I ,4-Ethyl-i-propylbenzene All 0.0002 0.0008 0.000 0.000 1,2,4,5-Tetramethylbenzene All 0.0002 0.0007 0.000 0.000 I ,2-Methyl-n-butylbenzene All 0.0001 0.0004 0.000 0.000 I ,2-Methyl-t-butylbenzene All 0.0002 0.0008 0.000 0.000 I ,2-Ethyl-n-propylbenzene All 0.0003 0.0012 0.000 0.000 2-Methylindan All 0.0001 0.0003 0.000 0.000 I ,3-Methyl-n-butylbenzene All 0.0001 0.0004 0.000 0.000 I ,3-Di-i-propylbenzene All 0.0001 0.0004 0.000 0.000 sec-Pentylbenzene All 0.0001 0.0004 0.000 0.000 n-Pentylbenzene All 0.0001 0.0004 0.000 0.000 I ,2-Di-n-propylbenzene All 0.0001 0.0004 0.000 0.000 I ,4-Di-i-propylbenzene All 0.0002 0.0008 0.000 0.000 Naphthalene AIO 0.0001 0.0003 0.000 0.000 UnknownCIIs Ull 0.0030 0.0123 0.002 0.002 n-Dodecane Pl2 0.0012 0.0054 0.001 0.001 I ,2,4-Triethylbenzene Al2 0.0002 0.0008 0.000 0.000 I ,2,3,4,5-Pentamethylbenzene Al3 0.0001 0.0004 0.000 0.000
2-Methylnaphthalene All 0.0001 0.0004 0.000 0.000 UnknownCI2s Ul2 0.0013 0.0053 0.001 0.001
n-Tridecane Pl3 0.0004 0.0019 0.000 0.000
UnknownC13s Ul3 0.0004 0.0019 0.000 0.000 n-Tetradecane Pl4 0.0002 0.0010 0.000 0.000 n-Pentadecane Pl5 0.0001 0.0005 0.000 0.000
UnknownCI5s Ul5 0.0001 0.0005 0.000 0.000
TOTAL 100.00000 100.00000 16.7483 16.8402
BTEX COMPONENTS MOLE% WT% BTU@ 14.650 14.730 BENZENE 0.0771 0.1585 LOW NET DRY REAL : 1548.8 /scf 1557.3 /scf TOLUENE 0.0486 0.1179 NET WET REAL : 1521.7 /scf 1530.2 /scf ETHYLBENZENE 0.0049 0.0137 HIGH GROSS DRY REAL : 1684.7 /scf 1693.9 /scf XYLENES 0.0179 0.0500 GROSS WET REAL : 1655.2 /scf 1664.4 /scf TOTALBTEX 0.1485 0.3401 NET DRY REAL : 15495.8 /lb 15580.4 /lb
GROSS DRY REAL : 16851.7 /lb 16943.8 /lb
RELATIVE DENSITY (AIR=1): 1.3107 (CALC: GPA STD2145 & [email protected] & 60F) COMPRESSIBILITY FACTOR : 0.99204 *(DETAILED HYDROCARBON ANALYSISINJ 1993) ; ASTA! D67 30
THIS DATA If AS BEEN ACQUIRED THROUGH APPLICATION OF CURRENT STATE-OF-T/IE-ART ANALlT/CAL TECHNIQUES.
THE USE OF THIS INFORMATION IS THE RESPONSIBLITY OF THE USER. EMPACT ANAL!TICAL SYSTEMS. ASSUMES NO
RESPONSIBLITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION.
Page 4
EMPACT Analytical Systems, Inc 365 S. Main Street, Brighton, CO 80601 303-637-0150
EXHIBITF
250
' :· .. .. . : .. 200
t 1\ \ \
Fidelity Cane Creek Unit 32-1-25-19 Gross Production and Flare Forecast
0.900
0.800
: : \ 0.700
c 150 u... u ~ ....... c Q.
0 co 100
50
:
' \ \
\_
..... \
0
May-14
: /''-. \ . I \
. : lo: I \ 0.600 . . I r···r· - ·~ ·~· ·~ .. Aen;al Jolumes : I : \ Fo ecasted Volu nes .. ~
::1 co
0.500 ~ u...
I :f\ '\ . I :1 \ \ : . : \ \
u ~
0.400 ;-0
~ : \ \ "' \ :I \ " 0.300
\ :; :1 -....... ._. v' \
""' f: :/ \. ~
\ ~ I :. :I \... -~ 0.200 ..__~ \ I :I ~ ~
•\ \ I :I r--...... ~
\ \I ~ 0.100
'\+ 7 .--- 0.000
Jul-14 Oct-14 Jan-15 Apr-15 Jul-15 Oct-15 Jan-16 Apr-16 Jul-16 Oct-16
-o- Production Forecast BOPD --+- Production Forecast MCFD --+---- Historical Production BOPD
--+---- Historical Production MCFD ...... ... Historical GOR ... ...... Forecasted GOR
EXHIBIT F -·1
CCU 32-1-25-19 Production Forecast
- iU > O:ryOil Y.. 0
~~ ~ t= I II I I ll1d -1~ 2i ~ E-~ I I I 1 I Qual FEP14Q4 ll_ =.; 2 r- 1 I , I Rei 21112015 ~ O ;: o ,___ Voct 153.320 -
8 ~ § t::-l --
o § o ~,........_.... , O o - : - a -
Vest 116.890 Qbeg 133.706
Qob 1.000 'b" 1.150000
, De 76.189655 Dmin 0.000
±~----~--~----!r-·-~~ Rem 97219 § Yrs 66. 083, ~
Cum 27548 8 EUR 124766
j
"- =1 ; ; I '· I d~ l I : ~ ---4
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~ ~ - ~--~ ·--=ts=:-~~--~ -- l -l ll--1 1 11 1-l l . ll ll ll-tl· I I-·--~-----~_~--~-~----T 1 -- '--~~
- § ;:; L1_t--J IL_J_·-·-;.,~-~~ \ S 0 - N-··' i5 I J
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I -1
......,
I ' i : I I ~ -r .:.:-Kr ----"A--·---·K,--·.l_j_l __ j_~-A-·--s---'--o _.J..._~~·--o--' 8
2015
• Pre-Gathering Gross Reserves ($50/bbl and $3/mcf flat pricing)
56.31 MBO
31.53 MMcf
Current average GOR at 580 scf/bbl
EXHIBIT~ - 2
EXHIBIT G
CCU 32-1-25-19 Economics
• Gas Gathering
Cost range from $1.28MM to $1.45MM to install gas gathering 16,530-ft, 10" trunkline, 2,110-ft 4" lateral! with compression at the wellsite $1,451,000
18,640-ft, 4", with wellsite compression $1,275,000
Additional potential road upgrade cost of $1MM
• Pre-Gathering Economics ($50/bbl and $3/mcf flat pricing)
PV10: ~$400M
• Post-Gather Economics ($50/bbl and $3/mcf flat pricing)
PV10: ($1845M}
• Post-Gather Economics ($90/bbl and $4.5/mcf flat pricing)
PV10: ($715M}
• Current average GOR at 580 scf/bb l
• Required production to support gathering insta llation= 450bbls/d at $50/bb l
At both low oil and high oil price environment, installing gathering lines to this well is not economic
EXH~BIY G -1.
Future Development of the 32-1-25-19 Well
Fidelity is currently planning for further development to support building a
gathering line (approximately 2.5 miles in length) to the 32-1-25-19 Well. The
wells in the development plan are required to provide the potential for enough
gas to justify the construction of the gathering line.
Current Locations:
• 32-2-25-19
• 32-3-25-19
• 36-1-25-18
These locations are subject to development and have the potential provide gas
volumes; however we are limited with respect to immediate drilling because of
the low oil price environment.
Future Locations: West Fertilizer
• 19-1-25-19
• 30-1-25-19
• 29-1-25-19
These locations are pending Environmental Assessment, which limits Fidelity's
ability to develop until approximately fall of 2016.
Hi I G-2
EXHIBITH
Alternative Option to Gathering Pipeline of the 32-1-25-19 Well
Gathering gas volumes has priority, as Fidelity has completed the construction of
gathering pipelines and a gas processing plant for the Cane Creek Unit Wells. We
have a vested interest to collect gas and supply our line from this location, once
development can further support construction costs. Fidelity does not find the
following alternative feasible or beneficial at present:
Gas Reinjection
• 12-24 month lead time with construction
• Large infrastructure on surface
•
o Compression and gas plant in area
o Visibly sensitive to area
Risk of adverse reservoir reaction
o Lifting potential allows for recycle only (not cost
effective)
• Geology of formation
o Analysis of injection potential is not understood
completely
• Single Well Injection
o Marginal production does not support the viability
of injection.
o Large CAPEX of $8 million would better serve
gathering line, given our interest to collect and
process gas to market.
EXHIBIT H
EXHIBIT Z
~
~ :.3 N
"" ' ''·
r ~ ____ __,_, ...
' El Complete items 1, 2, and 3. Also complete ' item 4 if Restricted Delivery is clesired.
liil Print your name and address on the reve~ so that we can return the card to you.
!iii Attach this card to the back of the mailpiece, or on the front if space permits.
1. Article Addressed to:
Bureau of Land Manag~erttfi'" Moab Field Office Attn: Eric Jones 82 East Dogwood Moab, UT 84532 .(.1050.061_ ----- --- ~-------------1
.J'
.~ ... ~ .. ~-
111 Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired.
Ill Print your name and address on the reverse so that we can return the card to you.
Ill Attach this card to the back of the mailpiece, or on the front if space permits.
1. Article Addressed to:
\
.Bureau of Land Mgmt.-Utah State-offi~i· Attn: Roger L. Bankert · ,, i440West200South,Suite500 · jl '-.'li~~o··-/
\
ISaltLakeCity, UT 84101 ' (1050.06) , ________ _
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I 7014 0510 0001 8171 1669
2. ArticleNumber 7014 0510 0001 8171 1676 1 2. Artic/eNumber ~~~~ ' I ~~~~
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1/2
BEFORE THE BOARD OF OIL, GAS AND MININGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FORAGENCY ACTION OF FIDELITYEXPLORATION & PRODUCTION COMPANYFOR AN ORDER AUTHORIZING THEFLARING OF GAS IN EXCESS OF THEAMOLTNTS ALLOWED UNDER UTAH ADMIN.coDE RULE R649-3-20(1.1) FROM THE CANECREEK UNIT 32-I-25-19 WELL LOCATED INSECTION 32, TOWNStIIP 25 SOUTH, RANGE 19EAST, SLM, GRAND COTINTY, UTAH
NOTICE OF HEARING
Docket No. 2015-01 ICause No. 196-45
THE STATE OF UTAH TO ALL PERSONS INTERESTED IN THE FOLLOWINGMATTER.
Notice is hereby given that the Board of Oil, Gas and Mining ("Board"), State of Utah,will conduct a hearing on WEDNESDAY, MARCH 25,2015, at 10:00 AM, or as soon thereafteras possible, in the auditorium of the Department of Natural Resources, 1594 West North Temple,Salt Lake City, Utah.
The hearing will be conducted as a formal administrative adjudication in accordance withthe rules of the Board as set forth in Utah Administrative Code R641 et seq., and as provided forin Utah Code Ann. $ 40-6-l et seq., and Utah Code Ann. $ 63G-4-101 through 601.
The purpose of the hearing will be for the Board to receive testimony and evidenceregarding a Request for Agency Action that the Board enter an Order:
1. Authorizing Fidelity or its successor(s) as Operator of the Cane Creek lJnit32-l-25-19 V/ell (the "Well"),located within Section 32, Township 25 South, Range l9 East, SLM,Grand County, Utah, to flare gas produced from said V/ell in an amount not to exceed 100MCFPD commencing on April 1,2015 and until such time as additional drilling and productionfrom nearby wells and economics justiff construction of a gathering line to collect the gas andtransport it to Fidelity's Dead Horse Lateral Pipeline and Processing Plant; and
2. Providing for such other and further relief as may be just and equitable under thecircumstances.
Objections to the Request for Agency Action must be filed with the Secretary of theBoard at the address listed below no later than the 1Oth day of March, 2015. A party must file atimely written objection or other response in order to participate as a party atthe Board hearing.Failure to participate can result in a default judgment.
Natural persons may appear and represent themselves before the Board. All otherrepresentation of parties before the Board will be by attorneys licensed to practice law in theState of Utah, or attomeys licensed to practice law in another jurisdiction which meet the rulesof the Utah State Bar for practicing law before the Utah Courts.
Persons interested in this matter may participate pursuant to the procedural rules of theBoard. The Request for Agency Action, and any subsequent pleadings, may be inspected at theoffice of the undersigned, and inspected online at the Utah Board of Oil, Gas and Mining'swebsite at
Pursuant to the Americans with Disabilities Act, persons requiring auxiliarycommunicative aids and services to enable them to participate in this hearing should callJulie Ann Carter at (801) 538-5277, at least three working days prior to the hearing date.
DATED this 26th day of FebruaÍy,2015.
STATE OF UTAHBOARD OF OIL, GAS AND MININGRuland J. Gill, Jr., Chairman
Secretary1594 V/est North Temple, Suite 1210Salt Lake City, Utah 84116(80r) s38-s277
/sl
2
CERTIFICATE OF' NOTICE
I hereby certify that I caused a true and correct copy of the foregoing NOTICE OFHEARING for Docket No. 2015-01I Cause No. 196-45 to be PUBLISHED in the followingnewspapers on the following days:
March 1,2015:The Salt Lake Tribune and Deseret Morning News, newspapers ofgeneral circulation in Salt Lake City and County.
March 5,2015:Times-Independent, a newspaper of general circulation in Emery and GrandCounties.
J
CERTIFICATE OF SERVICE
I hereby certify that on this2Tthday of Febrvary,2}ls,I caused a true and correct copy
of the foregoing NOTICE OF HEARING for Docket No. 2015-011, Cause No. 196-45, to be
mailed by Email or via First Class Mail with postage prepaid, to the following:
MacDonald & Miller MineralLegal Services, PLLCFrederick M. MacDonald, Esq.7090 S. Union Park Ave., Ste. 400Midvale, Utah84047
Steven F. Alder, Esq.Assistant Attorney General1594 West North Temple #300Salt Lake City, Utah 84116[Via Email]
ExxonMobil CorporationAttn: Ken Hilger, CPLP.O. Box 4610Corp-Wgr-702Houston, TX 77210-4610
Front Range Energy Investors LLCAttn: Land Department324 Garden StreetGolden, CO 80403
Bureau of Land Mgmt. - Utah State OfficeAttn: Roger L. Bankert440 V/est 200 South, Suite 500Salt Lake City, UT 84101
Fidelity Exploration & Production CompanyAttention: Wes Adams, Landman1801 Califomia St., Suite 2500Denver, CO 80202
Michael S. JohnsonAssistant Attorney General1594 West North Temple #300Salt Lake City, Utah 84116[Via Email]
FREI LLC-[Attn: Land Department324 Gañen StreetGolden, CO 80403
State of Utah School and Institutional TrustLands AdministrationAttn: Ms. Lavonne Garrison675 East 500 South, Suite 500Salt Lake City, UT 84102
Bureau of Land ManagementMoab Field OffrceAttn: Eric Jones82 East DogwoodMoab, UT 84532
4
CUSTOMERNAME AND
DIV OF OìL-GAS & MINING,Rose NoltonI594 V/NORTH TEMPLE STE I21O
,'1'ii' r \ .ltiill
SALT LAKE CITY
ACCOUNTNAME
ur *o?l%, 0F 0f1", GAS & MtNtN
DIV OF OIL-GAS & MINING,
ADORDER#TELEPHONE
0001014814
Starl 0310112015 End 0310112(
SCTIEDULE
CUST, REF. NO.
Docket 2015-0111012
CAPTION
NOTICE OF HEARING BEFORE THE BOARD OF OIL, GAS AND
SIZE
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3
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4770 S.5600 W.\\/ES]- VALLEY CITY, UTAìI 84I I8FITD.TAX I'D.# 87 -02 | 7 663801-204-6910
@1. ,ðultüake@rùhumc gPROOF OF PUBLICATION
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AS NEWSPAPER AGENCY COMPANY, LLC dba MEDI^.ONE OF UTAII L|CAL BOOKER, I
H
STATE OII IITÂH TO ÀLL PI,RSONS INI'IìIìESTED IN TI{E IIOLLO FOR DIV OF OIL-(AGENCY COMPANY, LLC dba MEDIAONE OF UTAIl, ACENT FOR TllE SAi.T LAKE ]'lìlBLTIIE ENCLISII LANGTJAGE WìTI.I GENERAL CIRCULATION IN U]'AH, AND PUBLISI'IED IN
tJTAH. NOTICE IS ALSO POSTED ON U]'AIILEGALS.COM ON THE SAME DAY AS TIIE FIIU'IAI]LEGALS.COM INDEFINA'TELY. COMPLIES W]TII UTAH DIGITAL SIGNATUIìB ACT'
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Obiectíons lo the Requestlsì for Ä.rency Action must be filed with lhe Secretory ofthe Boqrd ol the qddress tísted beiow. no tqfer thon th; i ott ;ä; äi¡vrordr, 20 r s.A.porly must fite o..timety wr¡nen obiect¡on ó, ónu, i"rþãnr"'ií J,:a", i",pã.riã_pole os o pqrty ot the Bodrd heqr¡ng. Fqirure to porticipoiJ än rãirrt ¡n o a"rorìtiudgmenl.Nclurol persons moy oppeor- ond rep^rêsent themselves before the Boqrd. All orherrepresentqrion of pqrt¡es before the Boqrd wiil be bt oiìr.iãvi t.ãñìro to prociicétq{ in the Stqre of Uroh, or onorney^s ticen_seo rJpiáhËã tö,i-n';Tåä;", iurisdicrionwhìdr meet rhe rutes of the utoh store aoi roi [råãt.,fr lq;"båfore the urohCourls,
ló,
DAIEDSTATE
lhis 2ólh doy of Februqry. 20l 5.OF I,JTAH
BOARD OF OIL, GAS AND MININGRuloncl J. Gill, Jr., Choimon/s/ Julie Ann CorterBoord Sectetqry
DATE 31212015
THIS IS NOT A S1'A1'EI\4ENT BUT A "PROOF OF PUBLICAIION''PLEASE PAY FROM BILLING STATEMENI-
Su¡le 'ì 2106
U
NOTARY SIGNATURE b
IJPÆOP
NOACE OF HEARINGDocKET No.2015-011
CAUSE NO.196'{5BEFORE THE BOARD OF OIL'
GASAND MININGDËPARTMENT OF NAÍURAL
RESOURCESSTATE OF UTAH
THE STATE OF UTAH TO ALLPERSONS INTERESTED IN THE
FOLLOWING MITTER:NOTICE IS HEREBY
GIVEN thatthe Board of Oil, Gas
and Mining ('Board"), State of
Utah, willconduct a hearing on
WEDNESDAY, MARCH 25, 201.5,
at 10:00 AM, or as soon thereaf'
ter as Possible, in the auditorium
of the Department of Natural
Resources, 1594 West North
Temple, Salt Lake CitY, Utah'
THE HEARING WILL BE
CONDUCTED as a formal admin-
istrative adjudication in accor-
dance with the rules of the Board
as set forth in Utah Administra-tive Code R641 et seq. and asprovided for in Utah Code Ann.
-ß 40-6-1 et seg., and Utah Code
Ann. -ß 40-8-1 et seq., and Utah
code Ann. -ß 63G-4-101 through601.
DOCKET NO. 2015-011
CAUSE NO. 196-45 - ln the Mat'ter of the Request for AgencY Ac-
tion of FIDELITY EXPLORATION& PRODUCTION COMPANY foran Order authorizing the flaringof gas in excess of the amounts
allówed under Utah Admin. CodeRule R649-3-20(1.1) from theCane Creek Unit 32-'l-25-'19 Welt
located in Section 32, TownshiP
25 South, Range 19 East, SLM,
Grand CountY, Utah.THE PURPOSEOFTHE
PROCEEDING will be for the
Proof of Publication
STATE OF UTAH,SS
County of Grand,
Zane \X/. Taylor, being first duly sworn accord-ing to law deposes and says: That he is the pubisher ofThe Times-Independent, a weeldy newspaper of generalcirculation, published every Thursday at Moab, GrandCounty, State of Utah, and a designated agent of the UtahPress Association; that the notice attached hereto andwhich is a copy of a
Utah Division of Oil, Gas and MiningIt{otice of HearingCause No. 196-45
which is made a part of this Affidavit of publication, waspublished in said newspaper for a period of 1 consecu-tive issues, the first publication date having been made
March 5,2015; and the last on
; and the said notice was published in each and every copyof said newspaper during the period and time of publica-tion, and that it was published in the newspaper properand not in a supplement thereof, and that said notice waspublished on Utahlegals.com on the same day as the firstnewspaper publication and the notice remained on Utah_legals.com throughout the period and time of print pub-lication.
bSubscribed and sworn b me this
)
)
)
Notary PublicResiding in Moab, Utah
My Commission ExpRhiono Noel MedinoNotory Pvblic Stote of UloltMy Commiseion Expiree on:
Jonuory 1 6' 2019Comm. Numbcr: ó81t l0
rìZZtol<t ej r,,13 j
Board to receive testidtþny andeú¡dence regarding a Requestfor Agency Action that the Boardenter an Order:
1. Authorizing Fidelity or itssuccessor(s) as OPerator of theCane Creek Unit 32-1-25-19 Well(the "well"), located within section32, Township 25 South, Range 19
East, SLM, Grand County, Utah,to flare gas produced from saidWell in an amount not to exceed100 MCFPD commencing on April1, 2015 and until such time asadditional drilling and productionfrom nearby wells and economicsjustify construction of a gatheringline to collect the gas and trans:port it to Fidelity's Dead HorseLateral Pipeline and ProcessingPlant;and
2. Providing for such otherand further relief as may be juòtand equitable under the circum-stances.
Objections to the Request(s)for Agency Action must be filedwith the Secretary of the Board atthe address listed below no laterthan the 10th day of March, 2015.A party must file a timely writ-ten objection or other responsein order to participate as a partyat the Board hearing. Failure toparticipate can result in a defaultjudgment.
Natural persons may appearand represent themselves beforethe Board. All other representa-tion of parties before the Boardwill be by attorneys licensed topractice law in the state of utah,or attorneys licensed to practicelaw in another jurisdiction whichmeet the rules of the Utah StateBar for practicing law before theUtah Courts.
Persons interested in thismatter may participate pursuant tothe procedural rules of the Board.The Request for Agency Action,and any subsequent pleadings,
. may be inspected at the office of' the undersigned, and inspected' online at the Utah Board of Oil,
Gas and Mining's website at http://ogm. utah. gov/am r/boardtemp/re-design/hooks.html.
Pursuant to the Americanswith D¡sabilities Act, personsrequiring auxiliary communica-tive aids and services to enablethem to partic¡pate in this hear-ing should call Julie Ann Carterat (801) 538.5277,.a|least threeworking days prior to the hearingdate.
DATED this 26th day of Feb-ruary 2015.
STATE OF UTAHBOAhD OF OIL, GAS
AND MININGr Ruland J. qitt, Jr., Chairman
/s/ Julie Ann CarterBoard Secretary
1594 West North Temple,
' s"rt Lake city, ,Î,illilî]8(801) 538-5277
Published in The Tmes-ln-,,dependent, Moab, Utah March 5,2015.
Julie Ann Carter, Board Secretary
State of Utah Board of Oil, Gas &Mining
1-594 West North Temple
Suite 121-0
Salt Lake City, Utah 84116
FILEDHAR 0 I 20t5
March 7,ZOLS
SECRETARÍ, BOAÐ OFoL qAs I Hiltiß
Subject: Docket 2015-011, Cause L96-45
Fidelity Well Number 32-7-25-79, API 43-0L9-50037 is located in a Federal Class I air quality district close
to Canyonlands National Park. Additional air pollution to this area must meet all current federal
restrictions.
The gas production from this well increased 1-7 times after fracking in November 2074. Flaring of thisgas will cause significant new air pollution in the Class I air quality district next to Canyonlands NationalPark. This is new gas from reworking the well. The Dead Horse Point Lateral Pipeline was built toprevent flaring of gas from this well.
This well was producing 244 MCF of gas in the 30 day reporting period of 10-1-2014 prior to fracking.
The well was fracked in November 2OL4, and gas produced increased to 4LO7 MCF in the 30 day
reporting period of L2-I-2OL4. The entire area is close to the current 75 ppb Federal limits for ozone
Any new pollution almost guarantees that the area will not meet the new EPA limits expected to be
published in the near future.
The BLM and Fidelity guaranteed that a new pipeline near the well would stop all flaring of gas.
Fidelity's request for additional flaring needs to be denied. The cost of a gathering line should not be
the reason to create additional air pollution in a Class I air district visited by over 500,000 people per
year.
Sincerely:
William E. Love
287LE Bench Rd.
Moab, Utah 84532
Julie Ann Carter, Board Secretary
State of Utah Board of Oil, Gas &Mining1594 West North Temple
Suite 1210
Salt Lake City, Utah 841.L6
March 8, 2015
Subject: Docket 2OLs-Ot1-, Cause 196-45
Fidelity Well Number 32-7-25-L9. API 43-019-50037 is located in a Federal Class I air quality district closeto Canyonlands National Park. Additional air pollution to this area must meet all current federalrestrictions.
For over two years Fidelity Exploration & Production has been granted waivers for gas flaring based onthe company's promise of completing and linking all it wells to the Dead Horse Point Lateral Pipeline.That pipeline is nearly completion, but still the company seeks a waiver to carry on flaring from this well.The company has blamed the BLM for delays in construction of the pipeline, but poor corporateplanning for working wíthin established regulations is equally responsíble for the delays. tt is time thatthe air quality for the citizens of Grand County and the half million visitors to Canyonlands National Park
and Dead Horse State Park takes precedent over Fidelity's concerns about costs.
The entire area in which this well is located is close to the current 75 ppm Federal limits for ozone. Anynew pollution generated by Fidelity being granted a waiver greatly increases the risk that the area willnot meet the new EPA limits expected to be published in the near future.
The BLM and Fidelity guaranteed that a new pipeline near the well would stop all flaring of gas.
Fidelity's request for additional flaring needs to be denied. The cost of a gathering line should not be
the reason to create additional air pollution in a Class I air district.
Sincerely,
/s/ William Rau, Ph.D.
William Rau, Ph.D.
HC 64 Box 3612
Castle Valley, UT 84532
¡N REPLY RËfËRÎO
rA2 (SEUG-RSS)
March 10,2015
Julie Ann Carter, Board SecretaryUtah Board of Oil, Gas and Mining1594 W. North TempleSuite l2l0Salt Lake City, UT 84116
United States Department of the InteriorNAT]ONAL PARK SERVICE
Southeast Utah GroupArches and Canyonhnds National Pnrks
Hovenweep and Natural Bridges National Monumcnts2282 S, West Resource Boulevard
Moab, utah 84532-3298
FILED
Dear Ms. Carter:
I am writing concerning the Matter of the Request for Agency Action of Fidelity Exploration &Production Company for an Order authorizing the flaring of gas in excess of the amountsallowed under utah Admin. code Rule R649-3-20(l.l) from the cane creek unir 32-l-25-lgWell located in Section 32, Township 25 South, Range l9 East, Salt Lake Meridian, GrandCounty, Utah- This well is located approximately 6 miles north of Canyonlands National Pa¡k.The National Park Service (NPS) has an interest in this Matter because of potential impacts ofexcessive gas flaring on air quality, the quality of dark night skies viewed from CanyonlandsNational Park, and the efficient use of natural resources. Because of this interest, NPS would tikethe opportunity to participate as a party in the Board hearing scheduled to be held on March 25,20r 5.
Sincerely
Kate CannonSuperintendent
Julie Ann Carter, Board Secretary
State of Utah Board of Oil, Gas & Mining
1594 West North Temple, Suite L210
Salt lake City, Utah 84776
FILEDilAR I { 20t5
SECRETARY, BOARDOFoLoas I imilNG
Subject: Docket 2O15-OLL, Cause 196-45
Link:
Canyonlands National Park, Moab residents and over 500,000 visitors to the Big Flats area just north ofCanyonland National Park were promised by the BLM and Fidelity in an Environmental Analyses (EA)
that the construction of the Dead Horse Po¡nt Lateral Pipeline would stop all flaring of gas, improve airquality, improve the economy of Moab, return the dark night skies in Canyonland National Park, andprevent the wasting of a valuable national resource. The Fidelity Oil and Exploration request to continueflaring of Well 3L-t-25-79 (APl 43-019-50037) will negate most of the reasons for the construction of thepipeline.
The link above is to the original EA (DO|-BLM-UT-Y01-0-2013-67 EA) prepared by the BLM for the Dead
Horse Lateral Pipeline. I have referenced several comments below from the EA, with the pdf page
numbers, which clearly show all the current and future benefits that would occur in the area fromeliminating flaring.
L. ( Page 2t) "The BLM's consideration of the Proposed Action responds to concerns regarding
the disposition of noturol gas, which is currently being flored, from existing product¡ve wells,
contrary to federol and state regulotions."
2. (Page45) "Observable flares, which are commonly seen ot night by nearby observers as wellas from viewers at distont viewpoints, would be eliminated."
3. (Page 50) "Emissions of pollutants and GHGs would be reduced by the delivery of notural gosto market via a pipeline rather thon destruction w¡th Ílores.
t'
4. (Page 79) "At night, the flores are visible from more distant locotions, including from ArchesNP and the Sand Flots Special Recreation Management Areo, located eost of Moab andapproximotely 20 miles oway. Visible flores compromise the oppeoronce of otherwise dork rurolnight skies."
5. (Page II9l "This gas is curcently flored on-site, with no economic benefit to governments frommineral royalties and/or severance toxes on production)"
6. Reduction in HAPS emissions with pipeline 42.7% Page 140
Table 4-15:
Fidelity and the BLM had many outstanding reasons to build the Dead Horse Point LateralPipeline to eliminate flaring from wells next to Canyonland National Park. The reasons arestill valid and permitting flaring of even one well partially negates the benefits of controllingair pollution. The flaring of one well will completely negates the promised benefits of thepipeline to Canyonlands National Park and the 500,000 people who use the area each year
Sincerely:
William Love2871 E Bench RdMoab, Utah 84532
Sourcc co NOx PMro PMz.s SOr VOCs llAP¡COzc
cml¡¡ions(tonncr/ycar)
Alternalives A and C-Cumulative Well Emissions 43.0 34.0 1.4 1.4 0 3737 54.41 33,341
Alternative B - Cumulative WellEmissions 780.3 169.5 1.4 1.4 0 1.571.4 94.8 328,524
lncrease in Well Emissionsthat would result fromAlternatÍve B
737.3 135,5 0 0 1,191 7 40.4 252,183
7o Decrease in Well Emissionsthat would result fromAlternatives A or C
94.5o/" 79.9o/o 76.2% 42.7"/o 89.9o/o
FILED
BEFORB THE BOARD OF OTL, cAS AND MININGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FOR AGENCYACTION OF FIDELITY EXPLORATION &,PRODUCTION COMPANY FOR AN ORDERAUTHORIZING TTIE FLARING OF GAS INEXCESS OF
THE AMOUNTS ALLOWED UNDER UTAH ADMIN.coDE RULE R649-3-20(l.l) FROM THE CANE CREEKUNIT 32-I-25-19 WELL LOCATED IN SECTION 32,TOWNSHIP 25 SOUTH, RANGE 19 EAST, SLM,GRAND COUNTY, UTAH
MOTION FOR DISMISSALWITHOUT PREJUDICE
Docket No. 2015-011
Cause No, 196-45
COMES NOW, Fidelity Exploration & Production Cornpany ("Fidelity"), acting by
and through its attorneys, MacDonald & Miller Mineral Legal Services, PLLC, and
pursuant to Utah Admin. Code Rule R641-105-300, and hereby respectfully requests the
lltah Boatd of Oil, Gas and Mining (the "Board") to dismiss Fidelity's Request for Agency
Action in this cause (the "RAA") without prejudice. Since responsive letters were filed by
William Rau, Williarn E. Love and the National Park Service, a fonnal dismissal by the
Board, rather than a mere voluntary withdlawal by Fidelity, is required. See, e,g., Utah
Rules of Civil Procedure Rule 4l(a).
The RAA was filed as a precautionary measure in the event the volumes of gas
produced from the Cane Creek [Jnit32-l-25-19 Well remained above the regulatory lirnits
for flaring under Utah Admin. Code Rule R649 -3-20(L 1). However, the volumes since the
filing ofthe RAA have now declined and are expected to stay belowthose regulatory lirnits,
rendering the need for extension of flarin gauthorization beyond March 31,2015 moot. The
RAA should therefore be dismissed without prejudice. A proposed Order of Dismissal is
submitted herewith.
Respectfully submitted this I 8tl' of Feb nrary, 20 I S .
MICDONALD & MILLER MINERALLEGAL SERVICES, PLLC
By:M. Esq.
7090 S. Union Park Ave., Ste. 400Midvale, Utah84047Telephone: (801) 676-0050Facsimile: (801) 676-0051E-Mail : fred@,rnacmillerlegal.com
Attorneys for Petitioner Fidelity Exploration& Production Company
1050.06
2
BEF'ORE THE BOARD OF OIL, GAS AND MININGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FOR AGENCYACTION OF FIDELITY EXPLORATION &,PRODUCTION COMPANY FOR AN ORDERAUTHORIZING THE FLARING OF GAS IN EXCESS OF
THE AMOUNTS ALLOWED UNDER UTAH ADMIN.coDE RULE R649-3-20(1.1) FROM THE CANE CREEK
UNIT 32-I.25-I9 WELL LOCATBD IN SECTION 32,
TOWNSHIP 25 SOUTH, RANGE lg EAST, SLM,GRAND COUNTY, UTAH
ORDER OF'DTSMISSALWITHOUT PREJUDICE
Docket No. 2015-011
Cause No. 196-45
The Board of Oil, Gas and Mining, having fully considered Fidelity Exploration &
Production Company's Motion for Dismissal Without Prejudice filed March 18, 2015, and
finding good cause therefor, hereby grants said Motion, Fidelity's Request for Agency
Action filed in this Cause is hereby dismissed without prejudice,
For all purposes, the Chairman's signature on a faxed copy of this Order shall be
deerned the equivalent of a signed original.
DATED this _ day of March,2}l5,
STATE OF'UTAHBOARD OF OIL, cAS AND MINING
By:
1050.06
Ruland J. Gill, Jr,, Chairman
CERTIFICATE OF SERVICE
I hereby certifii that, on this lSth day of March, 20I5,I caused a true and corectcopy of the foregoing Motion for Dismissal Without Prejudice and Proposed Order ofDismissal Without Prejudice to be sent electronically (where e-mail addresses areindicated) andlor mailed, postage pre-paid, to the following:
V/illiam Rau, Ph.D.HC 64 Box 3612Castle Valley, UT 84532
U.S. Department of the InteriorNat, Park Service - Southeast Utah GroupAttn: Kate Cannon, Superintendent2282 S. West Resource Blvd.Moab, UT 84532-3298
FREI LLC-TAttn: Land Department324 Gañen StreetGolden, CO 80403
State of Utah School and Institutional TrustLands AdrninistrationAttn: Ms. Lavonne Garrison6758ast500 South, Suite 500Salt Lake City, UT 84102E-mail: lavonnegarrison@utah. gov
Bureau of Land ManagementMoab Field OfflrceAttn: Eric Jones82 East DogwoodMoab, UT [email protected]
William E. Love28718. Bench RoadMoab, UT 84532
ExxonMobil CorporationAttn: Ken Hilger, CPLP.O. Box 4610Corp-Wgr-702Houston, TX 77210-4610
Front Range Energy Investors LLCAttn: Land Department324 Gañen StteetGolden, CO 80403
Bureau of Land Mgmt. - Utah StateOfficeAttn: Roger L. Bankert440 West 200 South, Suite 500Salt Lake City, UT 84101E-mail: [email protected]
Michael S. Johnson, Esq.Assistant Attorney GeneralAttorney for the Board of Oil, Gas andMiningP.O. 14s801Salt Lake City, UT 84114-5801E-rnail : mikej ohns on@utah. gov
J
Steven F. Alder, Esq.Assistant Attorney GeneralAttorney for the Division of Oil, Gas andMiningP.O. Box 145801salt Lake city, uT 84114-5801E-rnail : stevealder@utah. gov
M q
4
Julie Ann Carter, Board Secretary
State of Utah Board of Oil, Gas &Mining1594 West North Temple
Suite 1210
Salt Lake City, Utah 84L16
March\s,2ots F lL E DMAR I I 20t5
SæRETARY BC¡^ÐOFOL 0AS t tufifüG
Subject: Docket 2OL5-OLI, Cause L96-45 --Objection to Fidelity's Motion for DismissalWithout
Prejudice
I object to Fidelity Exploration and Production's Motion for Dismissalwithout Prejudice. The motion
needs to include the requirement that Fidelity cannot perform any hydraulic fracking or well
enhancement until the well to be fracked is connected to a gathering line to the Dead Horse Point
Lateral Pipeline.
Fidelity Exploration and Production and the BLM in their EA (DOl-BLM-UT-YO10-2014-0115EA1þlgIql
Gas Gatherins Line Svstem for the Dead Horse Point the Dead Horse Point Lateral Pioeline proposed toconstruct 19 gathering lines to 19 well pads to eliminate flaring in the Cane Creek Unit.
The 19 well pads that were to receive gathering lines are listed below in Table 2-1. lncluded among the
19 wells to receive gathering lines is well 32-1-25-19 (APl 43-019-50037). Note this is one of the shortestgathering lines in the area.
Well32-1-25-19 production was enhanced by fracking in November,2OL4 and has flared since then farmore gas than permitted under Utah Admin. Code Rule R649-3-20.
Fidelity must meet its commitment to the public by completing the 19 gathering lines and stop all flaring
in the Bíg Flats Cane Creek Unit before they are allowed to do further fracking or hydraulic
enhancement of any well in the area.
Flaring in view of two National Parks and a State Park partially destroys the park experience expected by
the more than 500,000 visitors to the areas. The parks are the primary source of income to the residents
and the businesses in Moab.
Data from (DOI-BLM-UT-Y010-2014-0115E4) Natural Gas Gathering Line System for the Dead Horse
Point Lateral Pipeline
gathering lines that rvould connect c ent and possibly future rvells on 19 rvell pads in and near
for liquids recov
Gathering Line Locat¡on
FederalSurfaceLength(feêtl
StateSurfaceLêngth(feet)
Total
Cane Creek (CC) 1-1 T25S-R19E, Sections 'l , 2 1,364 989 2.353
Cane Creek 2-1 T25S-R19E, Section 2 0 4,326 4,326
Cane Creek Unit 2-1-25-18 T25S-R18E, Section 2 0 't,693 1,693
Cane Creek Unit 7-'l T26S-R19E, Section 13T26S-R20E, Sections 7, 18
10,841 f0 't0,841 1
Cane Creek 8-1 T26S-R20E, Sections 8, 17, 18 4,293 0 4,293
Cane Creek Untt 12-1 T25S-R19E, Sections 1 1, 12 3,244 0 3,244
Cane Creek Unit 16-2 T25S-R18E, Sectíons'15, 16 't,037 2,133 3,170
Cane Creek UnÍt 17-1 T26S-R20E, 17,18 7.967 0 7.967
Cane Creek Unit l8-1 T26S-R20E, Section 18 1,375 0 1,375
Cane Creek 24-l T26S-R19E, Sections 13, 24 6,333 0 6,333
Cane Creek Un¡t26-2. T2SS-RI9E, Sections 26, 27 10,503 0 10,503
Table 2-l: Altemative A - Line and Land
1,1 19 0 1.'119Gane Creek Unil28-2 T25S-R19E, Sections 27, 28
Cane Creek Unit 32-1-25-19 T25S-R'19E, Section 32 0 2.535 2,535
Cane Creek 36-1-25-'18 T25S-R18E, Section 36T25S-R19E, Sections 27, 31-g 14.203 9,214 23.4't7
Cane Creek Unit 36-1T25S-Rí9E, Section 36T26S-R19E, Sections l, 2 976 1,403 2,379
Kane Springs Federal 'lG-1 S-R18E, Sections 35, 36T25S-R18E, Sections 2, 10,'l'¡,15 15,344 18.3ü) 33.
Kane Springs 19-14-ST T26S-R19E, Sections'13, 24T26S-R20E, Sections 19, 30 12.832 0 12.832
Kane Springs F ederal 27 -1T25S-R19E, Section 27 79 0 79
Kane Springs Federal25-19-U-1 T25S-R19E, Section 34 1,538 0 1,538
Total Length by Surface Owner 93,048 40,593 133,ô41
Sincerely:
William Love
287LE Bench Rd.
Moab, Utah 84532
FILEDl,lAR 2 3 2015
sEcRE[ ffÍ, nÐoF0t-,o^sl mililG
BEFORE THE BOARD OX'OIL, cAS AND MINTNGDEPARTMENT OF NATURAL RESOURCES
STATE OF UTAH
IN THE MATTER OF THE REQUEST FOR AGENCY
AcrroN oF FTDELTTY EXPLoRATToN &,
PRODUCTION COMPANY FOR AN ORDER
AUTHORIZING THE FLAzuNG OF GAS IN EXCESS OF
THE AMOUNTS ALLOWED UNDER UTAH ADMIN.coDE RULE R649-3-20(1.1) FROM THE CANE CREEK
UNIT 32-1-25-19 WELL LOCATED IN SECTION 32,
TOWNSHIP 25 SOUTH, RANGE 19 EAST, SLM,
GRAND COUNTY, UTAH
ORDER OF DISMISSALWITHOUT PREJUDICE
Docket No. 2015-011
Cause No. 196-45
The Board of Oil, Gas and Mining, having fully considered Fidelity Exploration &
Production Company's Motion for Dismissal Without Prejudice filed March 18,2015, and
hnding good cause therefor, hereby grants said Motion. Fidelity's Request for Agency
Action filed in this Cause is hereby dismissed without prejudice.
For all pu{poses, the Chairman's signature on a faxed copy of this Order shall be
deemed the equivalent of a signed original
DATED this day of March, 2015.
STATE OF UTAHBOARD OF OIL, GAS AND MINING
1050.06
By:J. Gill, Jr.,
CERTIFICATE OF SERVICE
I hereby certify that on this 26th day of March,2015,I caused a true and correct copy of
the foregoing ORDER OF DISMISSAL WITHOUT PREJUDICE for Docket No. 2015-011,
Cause No. 196-45, to be mailed by Email or via First Class Mail with postage prepaid, to the
following:
MacDonald & Miller MineralLegal Services, PLLCFrederick M. MacDonald, Esq.7090 S. Union Park Ave., Ste. 400Midvale, Utah 84047
Steven F. Alder, Esq.Assistant Attorney General1594 V/est North Temple #300Salt Lake'City, Utah 84116
[Via Email]
ExxonMobil CorporationAttn: Ken Hilger, CPLP.O. Box 4610Corp-Wgr-702Houston, TX 77210-4610
Front Range Energy Investors LLCAttn: Land Department324 Garden StreetGolden, CO 80403
Fidelity Exploration & ProductionCompanyAttention: Wes Adams, Landman1801 California St., Suite 2500Denver, CO 80202
Michael S. JohnsonAssistant Attomey General1594 West North Temple #300Salt Lake City, Utah 841l6[Via Email]
FREI LLC.IIAttn: Land Department324 Garden StreetGolden, CO 80403
State of Utah School and Institutional TrustLands AdministrationAttn: Ms. Lavonne Garrison675 East 500 South, Suite 500Salt Lake City, UT 84102
2
Bureau of Land Mgmt. - Utah State OfficeAttn: Roger L. Bankert440 West 200 South, Suite 500Salt Lake City, UT 84101
William Rau, Ph.D.HC 64Box36l2Castle Valley, UT 84532
[Address added 3 120 l20l5l
U.S. National Park ServiceSoutheast Utah GroupAttn: Kate Cannon - Superintendent2282 South ìùVest Resource Blvd.Moab, UT 84532-3298
[Address added 3 120 12015]
Bureau of Land ManagementMoab Field Off,rceAttn: Eric Jones82 East DogwoodMoab, UT 84532
William E. Love2871East Bench RoadMoab UT 84532
[Address added 3 120 l20l5l
3
