Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2017 Northstar-Kuparuk Oil PoolHilcorp Alaska, LLC
April 2nd, 2018
Hollis French, Chairman
Alaska Oil & Gas Conservation Commission
333 W. 7`h Avenue, Suite 100
Anchorage, Alaska 99501-3539
ECE]VE
APR 0 2 2018
AOGCV
Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8377
Fax: 907/777-8580
ckanyer@hilcorp.com
RE: NORTHSTAR UNIT, NORTHSTAR FIELD, NORTHSTAR KUPARUK OIL POOL, STATE OF ALASKA,
2017 ANNUAL RESERVOIR REVIEW
Dear Commissioner French:
In accordance with Conservation Order No. 739, Hilcorp Alaska, LLC ("Hilcorp"), as Operator, hereby submits for
your review the following Annual Reservoir Review for the Kuparuk Oil Pool in the Northstar Field.
Although submitted for the 2016 year, this will be considered the 111 Annual Reservoir Review under Conservation
Order No. 739, approved in January 2018. This report corresponds to events during the 2017 calendar year. Note
that the Northstar Field has been on production since November 2001, with the Kuparuk Oil Pool beginning
continuous production in November 2010.
A. Progress of Enhanced Recovery Project and Reservoir Management Summary
During 2017, no new wells were drilled or sidetracked in the Northstar Unit. Therefore the locations of all the wells
in the Northstar Unit have remained unchanged.
Production statistics are summarized in Table 1. Average daily oil production from the Kuparuk Oil Pool field was
3,233 bopd. The values reported include oil production from the NS -15 well beginning in August 2017.
During 2017, the negative reservoir voidage was calculated at 2,495.4 thousand -reservoir barrels (MRB). The
average of reservoir pressure for 2017 was 3,564 psia.
A compositional reservoir simulation model was further updated and utilized to continue progression of future
development scenarios prior to recompleting the NS -15 well into the Kuparuk A & C in 2017. This model was
matched to historical NS -08 & NS -18 production, PVT analysis, and reservoir pressure data gathered to date. Hilcorp
began development of a new reservoir simulation model with the geologic interpretation and additional well
performance data. This will be used in 2018 to verify future producer and gas injection location(s) to enhance
ultimate recovery of the Kuparuk reservoir.
Table 1: NORTHSTAR KUPARUK OIL POOL
2017 OVERVIEW STATISTICAL
SUMMARY
WELL STATISTICS
Injected Fluids
As of 12131/2017 Full year (1)
As of Dec -17 (2)
Net n e on
(Injection - Production)
Producers 3
3
Injectors 0
0
NOTES:
Flare 8
(1) Well count data reflects ONLY those w ells which contributed to productionlnjection during the respective
year
(2) Active w ells as of December 2017
Net Cum since
PRODUCTION/INJECTION STATISTICS
water,
voidage,
Year
Cumulative Start -
Formation
import Injection,
Up through
Production
2017
12131116
Oil (BBL)
1,180,165
4,323,431
Gas (MCF)
37,351,133
118,311,335
Water (BBL)
8,962
19,738
Injection
MRB Cum, MRB MRB
Jan -2017
Water (BBL)
0
0
Gas (MCF)
0
0
Balance (excludes satellite well NS -34A and Ivishak Production)
0
0
Cum Production (MRB)
2,495,414
5,885,151
Cum Injection (MRB)
0
0
Over/Under(MRB)
-2,495,414
-5,885,151
DAILY AVERAGE RATE DATA 2017
0
0
Production
0 0
Oil, BOPD
3,233
0
Gas, MCF/D
102,332
180,499
Water, BWPD
25
0
Injection
0
Water, BWPD
0
Apr -2017
Gas, MCFPD
0
685
AVERAGE RESERVOIR PRESSURE
700,738
2718,431
Average of surveys obtained in 2017
3,564
psia
B. Voidaee Balance by Month of Produced Fluid and Infected Fluids - 2017
Page 2
Produced Fluids
Injected Fluids
Net n e on
(Injection - Production)
Total
Flare 8
Total
Year
Cum since
Net Cum since
water,
voidage,
Year
Cum since
Formation
import Injection,
Cum,
start-up,
Injection, Year start-up,
Month
Oil, MRB
Free Gas, MRB
MRB
MRB
Cum, MRB start-up. MRB
Gas, MRB Gas, MRB
MRB
MRB
MRB
MRB Cum, MRB MRB
Jan -2017
0
183,646
1,238
183646
183,646
2,201,338
0
0
0
0 0
-183,646 -183,646 -2,201,338
Feb2017
0
10,791
155
165,791
349,437
$367,130
0
0
0
0 0
-10,,791 349,437 -2,367,130
Mar -2017
0
160,499
618
180,499
529,936
2,547,629
0
0
0
0 0
-180,499 529,936-ZW,,629
Apr -2017
0
170,802
685
170,802
700,738
2718,431
0
0
0
0 0
-170,802 -700,738 -2,718,431
May 2017
0
166,080
718
166,080
866,818
2,884,511
0
0.
0
0 0
-166080 466818 -2,884,511
Jun20170
151,876
653
151,876
1,018,694
3,036386
0
0
0
0 0
-151,876 -1,018,694 3,036,386
Jul -2017
0
165,787
908
165,787
1,184,481
3,202,174
0
0
0
0 0
-165,767 -1,184,481 -3,202,174
Aug -2017
0
156957
695
156,957
1,341,438
3359,131
0
0
0
0 0
-156,957 -1,341,438 -3,359,131
Sep 2017
0
214,281
892
214,281
1,555,720
3,573,412
0
0
0
0 0
-214,281 -1,555,720 3,573,412
Oct20170
305,978
802
306,978
1,862,697
3.880;390
0
0
0
0 0
-306978 -1,862,697 3,880,390
N.2017
0
294,950
761
2 1950
2,157,648
4,175340
0
0
0
0 0
-29g9W -2157,648 4,175,340
Dec -2017
0
337,766
853
337,766
2495414
4,513,106
0
0
0
0 0
337,766 -2,495,414 4513,106
W17 Totals
0
1,195,414
8,979
2,495,414
0
0
0
-2496414
Page 2
C. Summary and Analysis of reservoir pressure surveys within the pool
Static bottom hole pressures collected in 2017 are summarized below. Please note this data includes Ivishak
reservoir pressure data.
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Page 3
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operetor:
Hlcorp Alaska,
LLC
2. Mitres.:
3800 Centerpolnt
6 Suite 1400,
Anchorage AK 99503
3. WL or Lease Wrre:
Wrthater Wit
4. Fetl antl Pool: fbdM1star FieNL
WMstar OhSlW"ruk 01 Pool
S. Oatum Reference:
-11,1001-9,000
6.01 Gravity: Z Gas Gravity:
44/47 075
8. NO tarn,
antl Weber
9. AR Nuaber
50�
NO MslS
10. Type
See
klstruckons
11. AOGCC
Pool Cotle
12. Zane
13, Porforatetl 14. Final
Intervals Top Test We
Bottom Nl35S
15, Shut.
bTlre,
(burs
16. press.
Surv. Type
(see
gslmckons
for cotles)
17. 911.
Tenp,
18, Depth
Tool
WWS
19. Final
Meervetl
Ressure at
Tool Oepth
20. Wtum
wlS
(input)
21. pressure
Cxaeient,
psgft.
22. pressure
at Wbre
(cal)pag
NS -09
50029230520000
O
590100
Iushak
11,063'-11,085' 4/13/17
414.7
SBHP
247.8
10,855
5,106
11,100
0.08
5,126
NS -13
50029230170000
O
590100
Iushak
11,056'-11,090' 4/14/17
1185
SBHP
249.2
10,800
5,143
11,100
0.10
5,173
NS 08
50029230680000
O
590150
Kuparuk
8,924'-8,961' 5/8/17
53.9
SBHP
174
8,755
3,530
9,000
0.09
3,553
NS -07
50029230810000
O
590100
Iushak
11,111'-11,125' 6/5/17
58.5
SBHP
253.4
10,900
5,151
11,100
0.10
5,172
NS -15 j
50029230730000
O
590100
Itishak
11,037'-11,087' 7/2/17
16404
SBHP
247.4
11,000
5,160
11,100
0.40
5,199
NS -34A
50029233010100
O
590100 Itishak/Fitl
11,047-11,091' 7/8/17
109.5
SBHP
252.1
11,100
4,986
11.100
0.42
4,986
NS -06
50029230880000
O
590100
Iushak
11,036-11,155' 7/31/17
292.9
SBHP
252.6
11,027
5,156
11,100
0.10
5,163
NS -25
50029231810000
O
590100
Iushak
11,053'-11.203' 8/24/17
432.3
SBHP
224.5
11,000
5,153
11,100
0.11
5,153
NS -14A
50029230260100
O
590100
Iushak
11,089'-11,092' 10/26/17
135
SBHP
253
11,000
5,227
11,100
0.10
5,227
NS -19
50029230520000
O
590100
Iushak
11,118'-11,140' 11/27/17
211
SBHP
252
10,900
5,156
11,100
0.10
5,176
NS -15
50029230730000
O
590150
Kuparuk
9,082'-9,087' 9/17/17
26.6
SBHP
180.2
9,000
3,567
9,000
0.10
3,567
NS -15
50029230730000
O
590150
Kuparuk
8,940'-9,OBT 9/21/17
117.6
SBHP
185.6
9,000
3,572
9,000
0.10
3,572
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Page 3
D. Results and Analysis of Production and Infection log surveys, tracer surveys, observation well
surveys and any other special monitoring
No new Kuparuk production profiles were obtained in 2017 and summarized below.
There was no other special monitoring for this reporting period.
E. Review of pool production allocation factors and issues over the prior year
Theoretical production is calculated for each Northstar producing well on a daily basis.
2017 Production Allocation Method
A well's theoretical production is calculated using metered field volumes and hours on production as follows:
Gas Allocation
Gross Produced Gas = total return metered at test separator.
Net Produced Gas = Gross Produced Gas — Gaslift Gas.
Theoretical Produced Gas = all well tests Net Produced Gas prorated by the month.
(Proration calculation will include adjustments for shut in or downtime periods)
Field Gas Injection = metered prior to injection
Total Net Produced Gas = Field Gas Injection + Fuel Gas + Flare Gas + PPA Gas - Buy Gas
(Buy Gas = imported or Caribou Crossing acquired gas).
Total Net Produced Gas
Theoretical Produced Gas = Gas Allocation Factor
Gas Allocation Factor Theoretical Produced Gas (individual well) = Allocated Gas (individual well).
Oil Allocation
Actual Field Oil Production = oil volume metered by LACT (sold/delivered to Northstar crude oil pipeline)
(Adjusted for BS&W, temperature, and API gravity in accordance with API standards and BSEE regulations.)
Gross Produced Oil = total return metered at test separator.
Theoretical Well Oil Production = all well tests Gross Produced Oil prorated by the month.
(Proration calculation will include adjustments for shut in or downtime periods)
Theoretical Field Oil Production = Sum of Theoretical Well Oil Production
Field Natural Gas Liquid (NGL) Production = metered prior to commingling with oil
Actual Field Oil Production + Field NGL Production
Theoretical Field Oil Production = Oil Allocation Factor
Oil Allocation Factor x Theoretical Well Oil Production = Allocated Oil Production (individual well).
Water Allocation
Actual Field Water Production = water volume metered prior to injection disposal
Net Field Water Production = Actual Field Water Production — Metered Grey Water
Gross Produced Water = total metered at test separator.
Theoretical Well Water Production = all well tests Gross Produced Water prorated by the month.
(Proration calculation will include adjustments for shut in or downtime periods)
Theoretical Field Water Production = Sum of Theoretical Well Water Production
Page 4
Net Field Water Production
Theoretical Field Water Production = Water Allocation Factor
Water Allocation Factor x Theoretical Well Water Production = Allocated Water Production (individual well).
Northstar field allocation factors for 2017 averaged 1.36 for oil, 0.91 for water and 0.93 for gas. Oil allocation
factor was high due to allocation of NGL production. This data includes all Ivishak producers as well.
F. & G. Future Development Plans & Review of Annual Plan of Operations and Development
In 2017, Hilcorp increased unit production through well intervention projects, and other optimization
opportunities, that included the evaluation of shut-in wells for potential return to service. The full field study of
the Northstar Kuparuk Reservoir was continued. Well histories, review of production and injection data, material
balance calculations, geological, and geophysical work were updated. The Kuparuk compositional model was
updated with the NS -18 well results with a reasonable history match. This data was utilized to progress the
development plans of the Kuparuk reservoir, including the recompletion of the NS -15 well to the Kuparuk.
Projects completed during 2017 calendar year
• Fix surface casing leak in the NS -15 well.
• Abandon the Ivishak reservoir in the NS -15 and recomplete to the Kuparuk A & C sands.
• Acidize the NS -15 Kuparuk A2 sands.
In 2017, Hilcorp will pursue increased unit production through additional well intervention projects, any necessary
infrastructure and facility repairs, and other optimization opportunities as they arise.
No drilling activities are planned at Northstar within the 2018 calendar year.
The mobilization of a workover rig to the Northstar Island during the 2018 summer barging season is currently
planned for the NS -13 recompletion to Kuparuk project.
Proiects planned for the 2018 calendar vear
• Complete the 4th Stg Recycle Cooler Jumpers project to increase gas capacity in summer months to fully
optimize existing cooler capacity.
• Abandon the Ivishak reservoir in the NS -13 and recomplete to the Kuparuk A & C sands,
o Current plans include acidizing of the Kuparuk A2 sands.
• Acidize NS -08 and NS -18 production wells with documented near wellbore (skin) damage.
• Convert Kuparuk A & C reservoir producer into a gas injector.
Hilcorp will continue progress the Kuparuk reservoir study in the Northstar Unit. This may include re -mapping
productive horizons, updating well histories, reviewing production and injection data, material balance calculations,
and reviewing results of well intervention projects in 2017/2018. This will also include updating and development
of the current Kuparuk C geologic model.
Sincerely
Chris Ka nyer
Reservoir Engineer- Northstar
Page 5
