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2014 Milne Point Unit
RECEIVED Post Office Box 244027 �j Anchorage, AK 99524-4027 HilH LC J U L 0 2 2015 3800 Centerpoint Drive AO(�(�(�� Suite 100 GCC �. C Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 1, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Milne Point Unit Waterflood Surveillance Report, Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool Dear Commissioner Foerster, In accordance with the requirements of Conservation Orders 205 and 432D (Kuparuk River Oil Pool), Conservation Order 477 (Schrader Bluff Oil Pool), and Conservation Order 423 (Sag River Oil Pool), Hilcorp Alaska, LLC herby submits the consolidated Waterflood Surveillance Report for the Kuparuk River Oil Pool, Schrader Bluff Oil Pool, and Sag River Oil Pool. This report covers the time period January 1, 2014 through December 31,2014. Sincerely, nthony McConkey Reservoir Engineer Hilcorp Alaska, LLC Milne Point Unit Waterflood and Reservoir Surveillance Report for Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool January through December, 2014 Issued: July 1st, 2015 Sections and Exhibits Introduction Overview 1 Section 1: General Information Exhibit 1A Kuparuk River Oil Pool 2 Section 2: Kuparuk River Oil Pool Exhibits 2A — 2F Schrader Bluff Oil Pool 3 Section 3: Schrader Bluff Oil Pool Exhibits 3A — 3G Sag River Oil Pool 4 Section 4: Sag River Oil Pool Exhibits 4A — 4F Production/Injection Surveillance Logs 5 Section 5: Production/Injection Well Surveillance Exhibit 5A Shut in Well Exhibit Section 6: Shut in Well Status 6A Milne Point Well Testing and ASRC Unit 5 Summary 7 Section 7: Well Test Frequency and VSRD Meters 7A 6 ANNUAL RESERVOIR SURVEILLANCE REPORTS MILNE POINT UNIT KUPARUK RIVER OIL POOL SCHRADER BLUFF OIL POOL SAG RIVER OIL POOL JANUARY - DECEMBER 2014 Introduction As required by Conservation Order 205 for the Kuparuk River Oil Pool, approved October 4, 1984, Conservation Order 477, approved August 23, 2002 for the Schrader Bluff Oil Pool, Conservation Order 423 for the Sag River Oil Pool, approved May 6, 1998, and Conservation Order 550.007 for all Milne Point Pools, approved January 6, 2009, and Conservation Order 550.006 for all Milne Point Pools, amended February 14, 2014, this report provides a consolidated summary of surveillance activities within the Milne Point Unit. The report includes surveillance data associated with waterflood projects and development activities. The time period covered is January through December 2014. Order 205 for the Kuparuk River Oil Pool requires the Operator to submit the following for the previous calendar year: • A tabulation of reservoir pressure and injection pressure data on wells in the waterflood permit area. • A tabulation of all production logs, injection well surveys, and injection well performance data. • Produced fluid volumes (oil, gas, and water) and injected fluid volumes reported by month and on a cumulative basis. Order 477 for the Schrader Bluff Oil Pool requires the Operator to submit the following for the previous calendar year: • Progress of enhanced recovery project(s) implementation and reservoir management summary. • Voidage balance by month of produced fluids (oil, gas, and water) and injected fluids and cumulative status for each producing interval. 0 Summary and analysis of reservoir pressure surveys within the pool. • Results, and, where appropriate, analysis of production and injection logging surveys, tracer surveys and observation well surveys, and any other special monitoring. • Review of well testing and pool production allocation factors over the prior year. • Future development plans. • Review of Annual Plan of Operations and Development. Note: A separate Plan of Development is sent annually by October 1 as part of DNR reporting. Order 423 for the Sag River Oil Pool requires the Operator to submit the following for the previous calendar year: • Progress of enhanced recovery project implementation and reservoir management summary including engineering and geotechnical parameters. • Voidage balance by month of produced fluids and injected fluids and cumulative status. • Analysis of reservoir pressure within the pool. • Results, and, where appropriate, analysis of production logging surveys, tracer surveys and observation well surveys. • Review of pool allocation factors over the prior year. • Future development plans. Order 550.007 for All Milne Point Pools requires the Operator to submit the following for the previous calendar year: • A summary of the performance and operational issues relating to the Unit 5 MPFM. • The monthly oil, gas and water allocation factors for each Milne Point Field pool. Order 550.006 for All Milne Point Pools requires the Operator to submit the following for the previous calendar year: • A summary of all installations to date and the performance of each Gen 2 (VSRD meter). • All operational issues and any additional Gen 2 test results. Each of the three producing reservoirs is reported in a separate section. Section 1 General Information List of Exhibits Overview Statistical Summary 1-A Overview A miscible water -alternating -gas (MWAG) process was certified as an enhanced oil recovery project for the Milne Point Kuparuk reservoir on September 15, 1998. The MWAG process was in effect from December 2001 to December 2002. Since December 2002, a different enhanced oil recovery method, US -WAG (water -alternating -gas injection in an under -saturated reservoir) was started. During 2005, permitting was completed for implementation of a pilot WAG program in the Schrader Bluff. In 2006, the pilot commenced with injection into two E -pad injectors, MPE- 29 and MPE-25A. During 2007 and 2008, both E pad injectors continued WAG injection and WAG injection was discontinued in 2009. Currently, all gas is injected into dedicated gas injectors, MPE-02 and MPE-03. In May 2005, injection at L pad was converted from produced water injection to lower salinity Prince Creek source water injection as a means of potentially increasing recovery. Observation of resulting production and salinity trends has indicated a clear chemical, but indistinct production response. Bright Water TM is a polymer additive to injection water that alters sweep patterns within the reservoir with the purpose of improving oil recovery. A Bright Water TM trial was pumped in the Kuparuk reservoir in MPB-12i in 2004 and monitoring of this injection pattern continued through 2005-06. The 2004 treatment yielded a positive response. A second Bright Water TM program was deployed in 2007 in which MPE-23i and MPF -62i were treated. Results from the 2007 program are unclear due to metering issues. In 2009, an injection header Bright Water TM treatment was pumped at MPC -Pad, in which five wells were simultaneously treated (MPC -02i, 06i, 10i, 15i, 19i). Limited response from the 2009 program was seen in 2010. In 2011 a Bright Water TM trial was conducted on two Schrader Bluff injectors (MPJ -18 and MPH -15), but a clear response was not observed from this treatment. Possibly the volume of polymer was too small to be effective. In 2012 three Kuparuk wells were treated with Bright Water TM, MPF -84, MPF -88, & MPF -91. A 2013 review of the 2009 and 2012 Milne Kuparuk Bright Water TM treatments concluded that the magnitude of anticipated Bright WaterTM response was too small to detect with regards to the uncertainty in metering and fluctuations in watercut caused by shutting -in offset production wells. In June 2011 a tracer survey was initiated in 16 Milne Point Schrader Bluff injectors to gain further understanding of injector — producer connectivity. For a two week period all associated offset producers were sampled daily, and then switched to a weekly schedule. Daily composite samples were also taken at the Milne Point Plant. Two possible connections were identified from the tracer program and continue to be monitored, but in general little connection was observed between producers and injectors. In a 2012 tracer study, tracer was pumped down three Kuparuk injectors MPL-09, MPL-24, and MPL-08. Offset producers are sampled monthly. To date, breakthrough of tracer has not been detected. There were 7 CTD sidetracks drilled in 2014. Between March and June 2014, 3 producers (17- 53A, F -78A, & F -93A) and 4 injectors (F-30Ai, F-10Ai, F-74Ai, & F-09Ai) were sidetracked in the Kuparuk reservoir. All three producers were drilled as tri -laterals. The drilling campaign primarily targeted a redevelopment of the Kuparuk "A" sands. The purpose of the drilling campaign was to act as the 1St of 5 annual drilling campaigns that would utilize CTD as a major component of Milne Point's Area Development Plan. The remaining CTD drilling campaigns were discontinued following Hilcorp's acquisition of the field in November 2014. Hilcorp's focus will stem away from the Kuparuk CTD and initially invest primarily in rotary drilling in the Schrader Bluff reservoir. In 2014, 5 RWO's (rig workovers) were completed in the Schrader Bluff and 20 RWO's in the Kuparuk. There was also one RWO in the Ugnu, however this was not rate-adding - it was diagnostic work on MPS-39 in which the Poly-Core completion was pulled to identify the failure mechanism for future analysis. Exhibit 1-A provides well count, production and injection statistics for the Kuparuk River Oil Pool, the Schrader Bluff Oil Pool and the Sag River Oil Pool. During the report period of January through December 2014, field production averaged 19.4 MBOD, 10.6 MMSCFD (GOR 546 SCF/STB) and 70.2 MBWD (water cut 78%). Waterflood injection during this period averaged 89.8 MBWD with 1.6 MMSCFD of gas injection. The volumes above do not include Prince Creek Formation source water produced at F-pad for low salinity injection. As of December 31, 2014, cumulative water injection in the Kuparuk River Oil Pool was 518.0 MMSTB, while cumulative gas injection was 105.8 BSCF. Cumulative production was 246.3 MMSTB oil, 137.2 BSCF gas, and 340.7 MMSTB water. From first production to December 31, 2014, cumulative production exceeded injection by 77.6 MMRB. As of December 31, 2014, cumulative water injection in the Schrader Bluff Oil Pool was 157.7 MMSTB and cumulative gas injection in the Schrader Bluff Oil Pool was 220 MMSCF. Cumulative production was 72.8 MMSTB oil, 42.4 BSCF gas, and 65.6 MMSTB water. From first production to December 31, 2014, cumulative production has exceeded injection by 28.5 MMRB. Cumulative water injection in the Sag River Oil Pool from startup through December 2014 was 3.0 MMSTB, while cumulative gas injection was 324 MMSCF. Cumulative production was 2.6 MMSTB oil, 2.7 BSCF gas, and 2.5 MMSTB water. As of December 31, 2014, cumulative production exceeded injection by 3.9 MMRB. Exhibit 1-A Milne Point Unit 2014 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS As of 12/31/2013 Producers Injectors - WAG - Water Only - Gas Only As of 12/31/2014 Producers Injectors - WAG - Water Only - Gas Only Production Well Status in 2014 - Newly Drilled - Sidetracked or Redrilled Gas Injection Well Status in 2014 - Newly Drilled - Sidetracked or Redrilled WAG Injection Well Status in 2014 - Newly Drilled - Sidetracked or Redrilled Water Injection Well Status in 2014 - Newly Drilled - Sidetracked or Redrilled Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool 78 39 2 49 39 1 36 0 0 11 39 1 2 0 0 76 37 2 52 33 0 40 0 0 10 33 0 2 0 0 0 0 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 0 0 NOTES: (1) Well count reflects ONLY those wells that were operable at the time of interest. (2) Ugnu Tract Operation wells are not included in these statistics Exhibit 1-A (continued) Milne Point Unit 2014 OVERVIEW STATISTICAL SUMMARY PRODUCTION/INJECTION STATISTICS Cumulative Production Through 12/31/2014 Oil (MSTB) Gas (MMSCF) Water (MSTB) Cumulative Injection Through 12/31/2014 Water (MSTB) Gas (MMSCF) Cumulative Voidage Balance Through 12/31/2014 Cum. Production (MRB) Cum. Injection (MRB) Over/Under (MRB) AVERAGE RATE 2014 Production: Oil (MBD) Gas (MMSCFD) Water (MBD) Injection: Water (MBD) Gas (MMSCFD) AVERAGE OF PRESSURES OBTAINED IN 2014 (prig) - December 2014 Kuparu k River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool Ugnu Trial 246,296 72,782 2,702 122 137,225 42,983 2,780 24 337,708 65,596 2,467 18,889 516,234 157,680 3,020 0 105,808 220 324 0 688,437 184,876 7,003 0 611,285 159,567 3,277 19,313 -77,152 -25,309 -3,726 19,313 12.7 6.3 0.41 0.00 7.5 2.7 0.50 0.00 59.1 10.9 0.18 4.67 67.7 22.1 0.00 0.00 1.6 0.0 0.00 0.00 3,395 1,736 4,414 1,706 Section 2 Kuparuk River Oil Pool List of Exhibits Total Reservoir Production Plot 2-A Total Reservoir Injection Plot 2-B Pertinent Data Summary 2-C Reservoir Voidage Balance 2-D Static Pressure Data 2-E Injection Rate & Pressure Data By Well 2-F 100 90 80 m c D 70 c O m 60 v 0 50 a st 40 0 v 30 `m 20 10 0 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 Exhibit 2-A Hilcorp Alaska - Milne Point Unit Kuparuk Reservoir, Total Production R! OPINION 17 !FI fell lot TAINSION Ion an MAN SME, Oil Prod Cum KUP —411—Oil Prod Rate KUP Water Prod Cum KUP �— Water Prod Rate KUP Gas Prod Cum KUP --d— Gas Prod Rate KUP t Water Cut %, KUP t Producers Online —x— Gas/Oil Ratio KUP 1.0 0.9 0.8 0.7 0.6 0 0 0.5 a O 0.4 C7 0.3 0.2 0.1 0.0 1000000 100000 Exhibit 2-13 Hilcorp Alaska - Milne Point Unit Kuparuk Reservoir, Total Injection C c 1000 v m c d ?� 100 10000000 1000000 D li LL N 100000 a LL N N � � C C O 10000 a de •e N A > � O H 1000 10 1 I1t 1 1 iiii 1 I 1 1 1111-4-100 85 86 87 88 89 90 9192 93 94 95 96 97 98 99 00 0102 03 04 05 06 07 08 09 10 11 12 13 14 15 60 50 m 40 c J C O 12 30 0 m 'c w � 20 10 0 85 86 87 88 89 90 9192 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 Water Inj Cum KUP Water Inj Rate KUP - ^ Gas Inj Cum KUP —- Gas Inj Rate KUP Solvent Inj Cum KUP v— Solvent Inj Rate KUP Water Injectors OnLine Gas Injectors OnLine 0 MI Injectors OnLine hill 5&qwR mik;g, Water Injectors OnLine Gas Injectors OnLine 0 MI Injectors OnLine Kuparuk River Oil Pool Waterflood Project Summary The Kuparuk Rive Oil Pool is split up in Hydraulic Units which represent regions of the reservoir that are believed to be hydraulically isolated due to faulting and/or lithologic controls. There were 76 producing wells and 49 injection wells active through 2014. Exhibit 2-A shows a production plot for the Kuparuk River reservoir covering the entire project history through December 2014. The Kuparuk River Oil Pool oil production averaged 12.7 MSTBD for 2014 compared to 12.5 MSTBD in 2013. This represents an oil production increase of 1.6 % in 2014. Water production averaged 59.4 MBWD in 2014 and 54.4 MBWD in 2013, an increase of 8.4%. Gas production averaged 7.5 MMSCFD in 2014 and 9.1 MMSCFD in 2013, a decrease of 17.6%. Cumulative production since waterflood startup through the end of 2014 is 246.3 MMSTB of oil, 137.2 BSCF gas, and 340.7 MMSTB of water. Exhibit 2-13 shows an injection plot for the Kuparuk River reservoir covering the entire project history through December 2014. Water and gas injection rates averaged 67.7 MBWD and 1.6 MMSCFD for 2014. Injection rates in 2013 averaged 57.6 MBWD and 2.8 MMSCFD. This represents an increase in water injection of 17.5% (which was likely spurred by the reactivation of source water production/injection at K -pad) and a decrease in gas injection of 42.8%. The large decrease in gas injection was likely due to the shut-in of producers B-04 and B-09, which were both shut in for high GOR and gas handling constraints at the facility. Cumulative water injection since waterflood startup through the end of 2014 is 518.0 MMSTB and cumulative gas injection is 98.5 BSCF. Average water cut increased slightly from 81.3% in 2013 to 82.3% in 2014. Average GOR decreased from 724 SCF/STB in 2013 to 591 SCF/STB in 2014. Exhibit 2-C presents a summary of the pertinent production information for the Kuparuk River Oil Pool waterflood. Exhibit 2-D shows a monthly breakdown of production and injection data for the report period. This data shows that the voidage replacement ratio averaged 0.80 RB/RB in 2014. The VRR in 2013 averaged 0.81 RB/RB. This represents a slight decrease of 1.2%. The cumulative VRR for the reservoir is 0.89 RB/RB. Exhibit 2-E presents the reservoir pressure data taken during 2014 for the Kuparuk River wells. In 2014, 56 static pressure readings were obtained in the Kuparuk River reservoir, 41 from active producers and 15 from active injectors. Exhibit 2-F provides a 2014 monthly summary of individual well injection rate and injection pressure data for all of the Kuparuk River Oil Pool injectors. Exhibit 2-C Milne Point Unit - Kuparuk River Oil Pool SUMMARY OF PERTINENT DATA As of December 31, 2014 WATERFLOOD START-UP DATE: November 1985 PRODUCTION Prior to Waterflood Start -Up: Oil (MSTB) 0 Gas (MMSCF) 0 Water (MSTB) 0 Since Waterflood Start -Up: Oil (MSTB) 246,296 Gas (MMSCF) 137,225 Water (MSTB) 337,708 FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB) 516,234 Injection Gas (MMSCF) 105,808 Lean Gas (MMSCF) 97,386 Solvent (MMSCF) 8,422 AVERAGE OF PRESSURES OBTAINED IN 2014 Cal 7.000' TVD ss December, 2014 Pressure (psig) 3,395 WELL COUNT (Wells in Operation)* Production Wells 76 WAG Injection 40 Water Only Injection 10 Gas Only Injection 2 Notes: * Reflects ONLY operable wells. Exhibit 2-13 RESERVOIR VOIDAGE BALANCE Milne Point Unit Kuparuk River Oil Pool January - December 2014 Production: Injection: Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage Month Prod Rate Prod Rate Prod Rate Voidage Inj Rate Inj Rate Replacement Replacement Balance (stb/day) (slb/day) (mscf/day) (rbbl/day) (stb/day) (mscf/day) (rbbl/day) Ratio (rbbl/day) 1/31/2014 12,055 58,057 9,768 78,364 64,060 3,326 67,765 0.86 -10,599 2/28/2014 12,037 59,449 9,114 79,220 64,640 3,098 68,166 0.86 -11,054 3/31/2014 13,206 56,551 8,089 76,536 61,913 2,021 64,509 0.84 -12,028 4/30/2014 12,743 57,841 6,475 76,077 61,370 627 62,808 0.83 -13,269 5/31/2014 13,174 60,763 6,237 79,253 62,070 816 63,675 0.80 -15,578 6/30/2014 13,782 58,369 7,437 78,387 64,007 2,014 66,629 0.85 -11,758 7/31/2014 13,202 58,578 8,025 78,538 73,645 2,148 76,523 0.97 -2,015 8/31/2014 12,563 64,417 6,977 82,996 67,252 901 69,004 0.83 -13,992 9/30/2014 12,819 60,613 7,051 79,438 68,489 1,188 70,496 0.89 -8,942 10/31/2014 12,097 57,290 6,860 75,226 73,082 845 74,876 1.00 -350 11/30/2014 11,737 54,485 6,870 72,046 72,487 1,423 74,749 1.04 2,702 12/31/2014 13,350 62,865 7,054 82,227 78,975 928 80,926 0.98 -1,302 Average: 2014 12,730 59,106 7,496 78,193 67,666 1,611 70,010 0.90 -8,182 Cumulative: mstb mstb mmscf mrb mstb mmscf mrb mrb 31 -Dec -14 246,296 337,708 137,225 688,437 516,234 105,808 611285 0.89 -77,152 Page 1 Exhibit 2-E Static Pressure Data Kuparuk River Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator Hikorp Alaska, LLC, 12. Address: 3800 Centerpoint Dr, Anchorage AK 99503 3. Unit or Lease Na,,: Milne Point 4. Field and Pool: Ku ruk RNer Pool 5. Datum Rerere rm 7000' SS Oil Grav' : API -23 7. Gas Gravity: Air= 0.65 8. Well Name and Number 9. API Number 50.xxX-xXXx%-xx-xx 10. Oil (0) or Gas (G) 11. AOGCC Pool Code 72. Final Ted Data 13. Shut -In Tar..Hours 74. Press. Sun. Type (sea Instructions for codes) 15. B.H. Temp. 16. Depth Toel TVDss 17. Final Pressure at Taal Depth 18, Datum TVD. (input) 19. Pressure Gradient, psVll. 20, Comments Pressure at Datum (cal) Zane MPC -03 50-500-29207-86-00 PROD 525100 2/3/2014 138 SBHP 177 7,000 2,250 7000 0.345 2,250 Grad = 0.4284 psilft MPC -05 50-500-29212-44-00 Unknow n Tvm 525100 3/6/2014 166,777 SBHP 158 7,810 4,267 7000 0.278 4,042 Grad = 0.2781psi/ft MPC -05 50-500.29212-44-00 Unknow n T e 525100 2/27/2014 166,601 SBHP 159 7.810 4.264 7000 2.250 6,086 Grad = 0.6407 psVft MPC 05A 50-500.29212-44-01 PROD 1 525100 6/21/2014 1 936 SBHP 0 5.929 4.000 7000 0.419 4,449 Grad = 0.44 psVft B+C MPC -05A 50-500.29212-44-01 PROD 1 525100 2/27/2014 27,606 SBHP 177 7,063 4,486 7000 0.430 4 463 MPC -05A 50-500.29212-44-01 PROD 525100 2/14/2014 27,298 SBHP 178 7,053 4,488 7000 0.433 4,465 Grad = 0.4319 psift MPC -08 50-500.29212.77-00 INJ 525100 8/29/2014 44 SBHP 140 6,800 4,060 7000 0.320 4,124 TVD/SS=SS MPC -08 50.500.29212-77-00 INJ 525100 4/11/2014 3 SBHP 0 6,800 4,089 7000 0.340 4,157 MPC -19 50-500-2921504-00 INJ 525100 2/5/2014 846 SBHP 136 7,000 3,291 7000 #DIV/0I 3,291 Grad = 0.5288 psifft MPC -25A 50.500-29226-38-01 INJ 525100 3/13/2014 5,378 SBHP 163 7,000 5,065 7000 0.000 5,065 Grad - 0.429 psVft MPC -28A 50-500-29226-48-01 INJ 525100 2/4/2014 264 SBHP 129 7,000 4,649 7000 0.000 4,649 Grad = 0.4276 psVft MPC -36 50.500-29228-53-00 INJ 525100 4/10/2014 10 SBHP 0 7,000 5,263 7000 0.424 5,263 MPE-02 50-500-29214-17-00 INJ 525100 7/18/2014 1.283 SBHP 145 6,900 3,065 7000 0.120 3,077 MPE-04 50-500-29219-97-00 PROD 525100 5/4/2014 154 SBHP 179 6,542 1,111 7000 1 0.373 1,282 MPE-18 50-500-29227-48-00 PROD 525100 9/5/2014 57,237 SBHP 170 6,800 3,186 7000 0.420 3,270 MPs -19 50-500-29227-46-00 PROD 525100 3/23/2014 4,496 SBHP 183 6,789 1,482 7000 0.033 1,489 Grad 0.033 sift MPE-19 50-500-29227-46-00 PROD 525100 3/12/2014 4.221 SBHP 1 182 6,7891 1,461 7000 0.080 1,478 Grad -0.08 sift. MPF -01 50-500.2922552-00 PROD 525100 9/12/2014 3,011 SBHP 167 6,705 3,478 7000 0.437 3,607 MPF -01 50-500-2922552-00 PROD 525100 5/10/2014 480 PP 170 6,751 3,440 7000 0.434 PP READING CONVERTED TO 3 548 DATUM USING GRAD= 0.433 sVft A1+A2+A3 MPF -09 50-500.29227-73-00 PROD 525100 5/4/2014 264 PP 167 6,861 2,227 7000 0.432 PP READING C TO DATUM USING GRAD=0.433 2 287 PSI/FT. Al+q2+A3 MPF -18 50-500.29226-81-00 PROD 525100 5/4/2014 264 PP 174 7,011 2,8551 7000 0.455 P G CONVERTED TO DATUM USING GRAD = 0.433 2 850 PSUFT. Al+A2+A3 MPF -22 50-500-29226-32-00 PROD 525100 5/4/2014 264 PP 169 6,638 3,076 7000 0.434 PP READING CONVERT D TO DATUM USING GRAD = 0.433 3,233 PSIIFT Al MPF -25 50-500-2922546-00 PROD 525100 5/4/2014 264 PP 187 7,726 2,727 7000 0.433 PP READING CONVERTED TO DATUM USING GRAD = 0.433 2,413 PSVFT Al+A2+A3 MPF -45 50-500-2922556-00 PROD 525100 5/4/2014 264 PP 177 8958 2,031 7000 1 0.432 PP READING CONVERTED TO DATUM USING GRAD = 0.433 2,050 PSVFT Al+A2+A3 MPF -49 50-500-29227-32-00 INJ 525100 8/29/2014 16,512 SBHP 156 7,000 3,428 7000 0.444 3,428 MPF -53 50-500-2922578-00 Unknow n Type 525100 1/30/2014 2,852 SSHP 1686,900 3,117 7000 0.432 3,160 Grad = 0.4317 psVft MPF -53A 50-500.29225-78-01 PROD 525100 5/4/2014 264 PP 170 6,620 2,377 7000 0.434 PP READING CONVERTED TO DATUM USING GRAD = 0.433 2,542 PSVFT A1+A2+A3 MPF -53A 50-500-29225-78-01 PROD 525100 3/70/2014 PP 168 6820 2,956 7000 0.429 ro = I psim PP reading taken from DH ESP 3,119 au a prior'.st CTD POP Al+A2+A3 MPF -53A 50-500-29225-78-01 PROD 525100 1/31/2014 SBHP 188 8 898 3,120 7000 0.424 3,163 Grad = 0.4317 psi/ft; Initial SBHP MPF -54 50-500-29227-26-00 1 PROD 525100 1 11/8/2014 201 SBHP 165 1 7,0181 2,982 7000 0.367 2,976 Grad = 0.3659 sl/ft Exhibit 2-E Static Pressure Data Kuparuk River Oil Pool a. Noll Name and Number 9. API Number 50-XXX-XX%%X-XX-XX 10.03(0) 11. AOGCC Pool or Gas (G) Code 12. Final Test 13. Shut -In Date Time, Hours 14. Press. Surv. Type (see instructions for codes) 15.13.11. 16. Depth Tool Temp. TVD. 17. Final Pressure at Tool Depth 18. Datum TVD. (input) 19, Pressure 20. Comments Gradient, psi/ft . Pressure at Datum (ce6 Zone MPF -54 50-500-29227-26-00 PROD 525100 11/1/2014 41 SBHP 139 4,876 1,996 7000 0.483 3,022 G-ad=0.44 sift MPF -57A 50-500-29227-47-01 PROD 525100 5/4/2014 264 PP 160 6,304 3,069 7000 0.432 PP DING CONVERTED TO DATUM USING GRAD = 0.433 3,370 PSVFT A3 MPF -61 50-500-29225-82-00 PROD 525100 5/4/2014 264 PP 181 6930 1,321 7000 0.429 PP READING CONVERTED TO DATUM USING GRAD = 0.433 1,351 PSI/FT At-A2+A3+B MPF -70A 50-500-29226-03-01 INJ 525100 3/22/2014 SBHP 98 4,750 2,368 7000 0.440 3,358 GRAD - 0.4399 Psilft. Initial Test. MPF -78A 50-500-29225-99-01 PROD 525100 5/4/2014 264 PP 178 6,971 2,879 7000 0.448 PP READING CONVERTED TO DATUM USING GRAD = 0.433 2,892 PSI/FT Al+A2+A3 MPF -78A 50-500-29225-99-01 PROD 525100 3/24/2014 PP 177 6,971 3,321 7000 0.414 Grad = 0.44 PsLitt PP reading taken from DH ESP 3,333 ".u.,dor to st CTD POP At+A2+A3 MPF -83 50-500-29229-63-00 INJ 525100 1/26/2014 30,741 SBHP 152 6,713 3,998 7000 0.484 4.137 Grad = 0.4844 psVft MPF -86 50-500-29230-18-00 PROD 525100 6/8/2014 480 PP 168 6,732 2,848 7000 0.433 PP READING CONVERTED TO DATUM USING GRAD = 0.433 2,964 PSVFT At+A2+A3 MPF -93 50-500-29232-66-00 PROD 525100 5/21/2014 720 PP 139 5,756 2,676 7000 0.433 PP reading converted to datum 3,215 usingGrad = 0.433 s Vft At+A2+A3 MPF -93 50-500-29232-66-00 PROD 525100 4/14/2014 9,350 SBHP 139 5 717 2,855 7000 0.436 USED TVD 3,414 Grad = 0.4355 psVft MPF -94 50-500-29230-40-00 PROD 525100 11!7/2014 1,284 SBHP 182 7 250 3,241 7000 0.426 3.134 Grad = 0.4262 DsVft MPF -94 50-500-29230-40-00 PROD 52510010/1212014 658 SBHP 183 7,246 3,075 7000 0.424 2.971 Grad = 0.4245psi/ft MPK-37 50-500-29226-74-00 PROD 525100 2/23/2014 40.745 SBHP 165 6,8101 3.411 7000 0.438 3,494 Grad = 0.4375 psVft MPK-38 50-500-29226-49-00 PROD 525100 2/23/2014 43,497 SBHP 164 6,839 2,082 7000 0.206 2.115 Grad = 0.2057 sVft MPK-43A 50-500-29227-38-01 INJ 525100 3/4/2014 48.335 SBHP 125 7,119 2,207 7000 0.416 2,158 MPL-01A 50-500-29210-68-01 PROD 525100 6/13/2014 65,088 PP 167 6,709 4,175 7000 0.433 PP reading converted to datum 4,301 usina Grad = 0.433 psilft A2+A3 MPL-01A 50-500-29210-68-01 PROD 525100 4/16/2014 63,690 SBHP 162 6,659 4,188 7000 0.400 4,325 MPL-01A 50-500-29210-68-01 PROD 525100 3/23/2014 63,11 0SBHP 162 6,659 4,195 7000 0.400 4,332 Grad - 0.4004 psVft4 MPL-04 50-500-29220-29-00 PROD 525100 1/24/2014 570 SBHP 178 6,965 4.216 7000 0.375 4,229 Grad = 0.3745 sift MPL-04 50-500-29220-29-00 PROD 525100 1/21/2014 334 SBHP 178 6,965 4.198 7000 0.374 4,211 Grad=0.3745psi/ft MPL-04 50-500-29220-29-00 PROD 525100 1/9/2014 47 SBHP 81 6,965 4,085 7000 0.371 4,098 Glad = 0.3706 psVft MPL-09A 50.500-29220-75-01 INJ 525100 4/27/2014 289 SBHP 120 7,149 3,415 7000 0.443 3,349 MPL-10 50-500-29220-76-00 INJ 525100 6/25/2014 77 872 SBHP163 7,000 4 354 7000 0.375 4,354 TVD/SS DEPTH = TVD MPL-21 50-500-29226-29-00 INJ 525100 1/28/2014 126,209 SBHP 164 6 782 3,773 700 1 0.358 3 851 Grad = 0.3574 sift MPL-24 50-500-29225-60-00 INJ 525100 7/5/2014 19 SBHP 155 7,000 4118 7000 0.208 4,118 MPL-29 50-500-29225-43-00 PROD 525100 1/13/2014 808 SBHP 192 7,017 2,445 7000 1 0.359 1 39 Grad = 0.3582 Vft MPL-39 50-500-29227-88-00 PROD 525100 3/18/2014 SBHP 150 6,500 3,508 7000 0.376 3 898 Grad - 0.3762 sVft. _76,967, Avera e 3,395 21. All tests reported herein were m,d, in a nice Mm th—pipficable, rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby cenify that the f—wirm Is true and cerred to the best of my knoMede. signature Ttk Reservoir Engineer Printed Nam. Anthony McConkey Date 6/30/2015 FL Fluid Level PBU Pressure Build Up PFO Pressure Fall Off PPPump Pressure SBHP Shut -In Bottom Hole Pressure Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) B05Ai 1/1/2014 2398 31 67473 2177 B05Ai 2/1/2014 2277 28 94381 3371 B05Ai 3/1/2014 2319.333 3 1683.353 1683 B05Ai 4/1/2014 2617.917 24 20541.36 855.8899 B05Ai 5/1/2014 2641.516 31 27295.39 880.4963 B05Ai 6/1/2014 2491.9 30 32275.6 1075.853 B05Ai 7/1/2014 2556 31 30364 979 B05Ai 8/1/2014 2654 31 33921 1094 B05Ai 9/1/2014 2607 13 11533 887 B05Ai 10/1/2014 0 0 0 0 B05Ai 11/1/2014 0 0 0 0 B05Ai 12/1/2014 2497 24 35349 1473 B 12 i 1/1/2014 0 0 0 0 B12i 2/1/2014 0 0 0 0 B12i 3/1/2014 0 0 0 0 B12i 4/1/2014 0 0 0 0 B12i 5/1/2014 0 0 0 0 612i 6/1/2014 0 0 0 0 1312i 7/1/2014 0 0 0 0 B12i 8/1/2014 0 0 0 0 B12i 9/1/2014 0 0 0 0 B12i 10/1/2014 0 0 0 0 B12i 11/ 1/2014 0 0 0 0 1312i 12/1/2014 0 0 0 0 613i 9/1/2014 1376 19 51830 2728 613i 10/1/2014 1505 31 92832 2995 B13i 11/1/2014 1122 10 23361 2336 1313i 12/1/2014 1109 26 36780 1415 B14i 1/1/2014 0 0 0 0 B14i 2/1/2014 0 0 0 0 B14i 3/1/2014 0 0 0 0 1314i 4/1/2014 0 0 0 0 1314i 5/1/2014 0 0 0 0 1314i 6/1/2014 0 0 0 0 B14i 7/1/2014 0 0 0 0 1314i 8/1/2014 0 0 0 0 B14i 9/1/2014 0 0 0 0 614i 10/1/2014 0 0 0 0 B14i 11/1/2014 0 0 0 0 B14i 12/1/2014 0 0 0 0 B18i 1/1/2014 2016 31 29038 937 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) B18i 2/1/2014 2033 28 25524 912 B18i 3/1/2014 2029.226 31 27734.48 27734 B18i 4/1/2014 2064.733 30 27386.62 912.8875 B18i 5/1/2014 2072.516 31 30204.16 974.3278 B18i 6/1/2014 2010.133 30 26485.82 882.8607 1318i 7/1/2014 1987 31 25810 833 B18i 8/1/2014 2053 31 25796 832 B18i 9/1/2014 2065 30 25051 835 B18i 10/1/2014 2059 31 27056 873 B18i 11/1/2014 2113 30 26385 879 1318i 12/1/2014 2160 31 29015 936 B20 1/1/2014 2574 31 102113 3294 B20 2/1/2014 2512 28 91340 3262 B20 3/1/2014 2499.548 31 99984.82 99985 B20 4/1/2014 2329.167 30 90769.04 3025.635 B20 5/1/2014 2227.387 31 93798.95 3025.773 B20 6/1/2014 2235.4 30 90201.45 3006.715 B20 7/1/2014 2246 31 93134 3004 B20 8/1/2014 2258 31 94700 3055 B20 9/1/2014 2253 30 94306 3144 B20 10/1/2014 2168 31 92937 2998 B20 11/1/2014 2144 20 54017 2701 B20 12/1/2014 2256 31 96577 3115 CO2i 1/1/2014 2177 31 48894 1577 CO2i 2/1/2014 2121 28 40752 1455 CO2i 3/1/2014 2066.839 31 45223.07 45223 CO2i 4/1/2014 2084.4 30 44438.56 1481.285 CO2i 5/1/2014 2074.161 31 47869 1544.161 CO2i 6/1/2014 1979.2 30 42584.11 1419.47 CO2i 7/1/2014 1876 31 44385 1432 CO2i 8/1/2014 1823 31 44791 1445 CO2i 9/1/2014 1926 30 44817 1494 CO2i 10/1/2014 1451 31 22414 723 CO2i 11/1/2014 1434 30 24080 803 CO2i 12/1/2014 1314 31 22835 737 C06i 1/1/2014 1998 31 82141 2650 C06i 2/1/2014 2005 28 73791 2635 C06i 3/1/2014 1990.323 31 79515.02 79515 C06i 4/1/2014 2027.367 30 77265.21 2575.507 C06i 5/1/2014 2014.387 31 80419.84 2594.188 C06i 6/1/2014 2012.733 30 74417.39 2480.58 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) C06i 7/1/2014 1951 31 77919 2514 C06i 8/1/2014 1946 31 77746 2508 C06i 9/1/2014 2057 30 77159 2572 C06i 10/1/2014 1980 31 77838 2511 C06i 11/1/2014 2049 30 79865 2662 C06i 12/1/2014 2019 31 76773 2477 C08i 1/1/2014 0 0 0 0 C08i 2/1/2014 0 0 0 0 C08i 3/1/2014 0 0 0 0 C08i 4/1/2014 0 0 0 0 C08i 5/1/2014 0 0 0 0 C08i 6/1/2014 0 0 0 0 C08i 7/1/2014 0 0 0 0 C08i 8/1/2014 0 0 0 0 CO8i 9/1/2014 0 0 0 0 C10i 1/1/2014 3289 31 61067 1970 C10i 2/1/2014 3292 28 54696 1953 C10i 3/1/2014 3303.065 31 61295.98 61296 C10i 4/1/2014 3306.6 30 58744.95 1958.165 C10i 5/1/2014 3332.452 31 60878.07 1963.809 C10i 6/1/2014 3282.8 30 58434.04 1947.801 C10i 7/1/2014 3153 31 58577 1890 C10i 8/1/2014 3215 29 55117 1901 C10i 9/1/2014 3151 30 54368 1812 C10i 10/1/2014 3284 30 56870 1896 C10i 11/1/2014 3309 30 56723 1891 C10i 12/1/2014 3331 31 58827 1898 C15i 1/1/2014 2124 31 23183 748 C15i 2/1/2014 2132 28 20493 732 C15i 3/1/2014 2112.806 31 23109.54 23110 C15i 4/1/2014 2158.433 30 24221.46 807.3821 C15i 5/1/2014 2184.194 31 25117.99 810.2578 C15i 6/1/2014 2110.567 30 23349.64 778.3212 C15i 7/1/2014 2010 31 22598 729 C15i 8/1/2014 2027 30 21250 708 C15i 9/1/2014 1978 30 21916 731 C15i 10/1/2014 2306 31 45362 1463 C15i 11/1/2014 2454 30 43155 1438 C15i 12/1/2014 2536 31 46974 1515 C19i 1/1/2014 0 0 0 0 C19i 2/1/2014 0 0 0 0 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) C19i 3/1/2014 0 0 0 0 C19i 4/1/2014 0 0 0 0 C19i 5/1/2014 1226.375 8 8132.602 1016.575 C19i 6/1/2014 1236.667 30 29463.57 982.1192 C19i 7/1/2014 1202 31 30881 996 C19i 8/1/2014 1318 14 15013 1072 C19i 9/1/2014 0 0 0 0 C19i 10/1/2014 0 0 0 0 C19i 11/ 1/2014 0 0 0 0 C19i 12/1/2014 1255 31 29534 953 C25Ai 1/1/2014 0 0 0 0 C25Ai 2/1/2014 0 0 0 0 C25Ai 3/1/2014 0 0 0 0 C25Ai 4/1/2014 0 0 0 0 C25Ai 5/1/2014 0 0 0 0 C25Ai 6/1/2014 0 0 0 0 C25Ai 7/1/2014 0 0 0 0 C25Ai 8/1/2014 0 0 0 0 C25Ai 9/1/2014 0 0 0 0 C25Ai 10/1/2014 0 0 0 0 C25Ai 11/1/2014 0 0 0 0 C25Ai 12/1/2014 0 0 0 0 C28Ai 1/1/2014 2073 23 27360 1190 C28Ai 2/1/2014 1990 25 30829 1233 C28Ai 3/1/2014 2121.871 31 46274.79 46275 C28Ai 4/1/2014 2191.533 30 49275.68 1642.523 C28Ai 5/1/2014 2246.419 31 48086.39 1551.174 C28Ai 6/1/2014 2246.3 30 48942.88 1631.429 C28Ai 7/1/2014 2169 31 45064 1454 C28Ai 8/1/2014 2196 31 46999 1516 C28Ai 9/1/2014 2350 30 48060 1602 C28Ai 10/1/2014 2324 31 47712 1539 C28Ai 11/1/2014 2394 30 44840 1495 C28Ai 12/1/2014 2427 31 48959 1579 C36i 1/1/2014 3055 31 49317 1591 C36i 2/1/2014 2966 22 32027 1456 C36i 3/1/2014 0 0 0 0 C36i 4/1/2014 2727.632 19 28402.3 1494.858 C36i 5/1/2014 2828.88 25 36922.05 1476.882 C36i 6/1/2014 2371 4 4875.875 1218.969 C36i 7/1/2014 2708 30 45058 1502 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) C36i 8/1/2014 2876 29 43769 1509 C36i 9/1/2014 2895 30 45630 1521 C36i 10/1/2014 3025 30 48061 1602 C36i 11/1/2014 3070 30 49912 1664 C36i 12/1/2014 3091 31 50071 1615 C39i 1/1/2014 2986 31 25171 812 C39i 2/1/2014 3006 28 23068 824 C39i 3/1/2014 3138.581 31 35892.32 35892 C39i 4/1/2014 3199.2 30 34441.21 1148.04 C39i 5/1/2014 3249.774 31 37583.62 1212.375 C39i 6/1/2014 3214.4 30 34987.53 1166.251 C39i 7/1/2014 3107 31 35613 1149 C39i 8/1/2014 3295 28 34920 1247 C39i 9/1/2014 3141 30 33085 1103 C39i 10/1/2014 3249 29 33858 1168 C39i 11/1/2014 3292 30 36194 1206 C39i 12/1/2014 3306 31 37511 1210 C42i 1/1/2014 2540 31 29280 945 C42i 2/1/2014 2580 28 26396 943 C42i 3/1/2014 2591.29 31 30423.88 30424 C42i 4/1/2014 2643.967 30 31028.73 1034.291 C42i 5/1/2014 2695.194 31 32913.65 1061.731 C42i 6/1/2014 2674.067 30 30977.89 1032.596 C42i 7/1/2014 2614 31 30754 992 C42i 8/1/2014 2772 28 29705 1061 C42i 9/1/2014 2669 30 28335 945 C42i 10/1/2014 2777 30 30662 1022 C42i 11/1/2014 2803 30 32508 1084 C42i 12/1/2014 2826 31 31065 1002 E05i 1/1/2014 2063 31 39362 1270 E05i 2/1/2014 2082 28 38303 1368 E05i 3/1/2014 2054.065 31 37084.31 37084 E05i 4/1/2014 2052.6 30 31707.3 1056.91 E05i 5/1/2014 2047.452 31 31038.25 1001.234 E05i 6/1/2014 2051.833 30 30995.55 1033.185 E05i 7/1/2014 2070 31 32302 1042 E05i 8/1/2014 2072 31 32842 1059 E05i 9/1/2014 2068 30 29471 982 E05i 10/1/2014 2005 31 28861 931 E05i 11/1/2014 2076 30 28627 954 E05i 12/1/2014 2105 31 31951 1031 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) E07i 1/1/2014 1699 31 77959 2515 E07i 2/1/2014 1914 28 66609 2379 E07i 3/1/2014 2236.645 31 95303.37 95303 E07i 4/1/2014 2220.967 30 84557.53 2818.584 E07i 5/1/2014 2306.419 31 85834.26 2768.847 E07i 6/1/2014 2437.3 30 89018.15 2967.272 E07i 7/1/2014 2543 31 98244 3169 E07i 8/1/2014 2560 31 92152 2973 E07i 9/1/2014 2582 30 87672 2922 E07i 10/1/2014 2517 31 89798 2897 E07i 11/1/2014 2457 30 77847 2595 E07i 12/1/2014 2591 31 92424 2981 E17i 1/1/2014 2118 26 77625 2986 E17i 2/1/2014 2166 28 87197 3114 E17i 3/1/2014 2154.379 29 82691.8 82692 E17i 4/1/2014 2140.2 30 82599.12 2753.304 E17i 5/1/2014 2104.871 31 83464.46 2692.402 E17i 6/1/2014 2078 30 71390.44 2379.681 E17i 7/1/2014 2169 31 91985 2967 E17i 8/1/2014 2136 31 87256 2815 E17i 9/1/2014 2096 30 80505 2684 E17i 10/1/2014 2151 29 91122 3142 E17i 11/1/2014 2398 5 17548 3510 E17i 12/1/2014 2278 31 102884 3319 E23i 1/1/2014 2322 31 103201 3329 E23i 2/1/2014 2370 28 95565 3413 E23i 3/1/2014 2591.419 31 121844.8 121845 E23i 4/1/2014 2583.3 30 117415.4 3913.847 E23i 5/1/2014 2581.774 31 125633.2 4052.683 E23i 6/1/2014 2548.733 30 119436.8 3981.227 E23i 7/1/2014 2539 31 123390 3980 E23i 8/1/2014 2569 31 124617 4020 E23i 9/1/2014 2387 30 110509 3684 E23i 10/1/2014 2259 31 108491 3500 E23i 11/1/2014 2279 30 110982 3699 E23i 12/1/2014 2149 31 116768 3767 E26i 1/1/2014 2045 31 34917 1126 E26i 2/1/2014 2076 28 31852 1138 E26i 3/1/2014 2041.161 31 31392.53 31393 E26i 4/1/2014 2046.667 30 31831.45 1061.048 E26i 5/1/2014 2076.323 31 36686.39 1183.432 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Well E26i E26i E26i E26i E26i E26i E26i F10i F10i F10i F10i F10i F10i F10i F10i F10i F10i F10i F10i F13i F13i F13i F13i F13i F13i F13i F13i F13i F13i F13i F13i F26i F26i F26i F26i F26i F26i F26i F26i F26i F26i Month 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 WH Pressure Avg (psi) 2058.367 2053 1992 1900 1901 1914 1886 2270 2298 2209.742 2086.8 1800.806 1716.433 1802 1645 1639 1595 1570 1538 2064 2240 2408.839 2345.667 2144.387 2313.133 2797 2588 0 1710 2201 2426 2299 2364 1930.129 1464.333 1140.355 1096.467 1411 1434 1423 1248 Days Operating 30 31 31 30 31 30 31 31 28 31 30 31 30 31 31 30 31 30 31 31 28 31 30 31 30 31 9 0 21 30 31 31 28 31 30 31 30 31 31 30 31 Inj Vol Calc. (BBL, MCF) 32569.15 32446 29967 26734 30690 25605 27429 45534 41487 40842.9 33797.53 23993.68 24304.01 31428 25362 26158 26583 25758 26564 32701 35692 39684.79 33815.1 28703.49 36999.12 57009 11650 0 25882 42758 45727 63790 57197 32917.05 20309.73 17979.48 23785.05 48622 42865 35926 33652 Injection Rate Avg. (BWPD) 1085.638 1047 967 891 990 854 885 1469 1482 40843 1126.584 773.9897 810.1337 1014 818 872 858 859 857 1055 1275 39685 1127.17 925.9189 1233.304 1839 1294 0 1232 1425 1475 2058 2043 32917 676.9911 579.9831 792.8351 1568 1383 1198 1086 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) F26i 11/1/2014 1385 30 43495 1450 F26i 12/1/2014 1430 31 41473 1338 F30Ai 5/1/2014 0 0 0 0 F30Ai 6/1/2014 0 0 0 0 F30Ai 7/1/2014 2085 27 65984 2444 F30Ai 8/1/2014 2294 30 47592 1586 F30Ai 9/1/2014 2140 30 35339 1178 F30Ai 10/1/2014 2399 31 65216 2104 F30Ai 11/1/2014 3067 30 84851 2828 F30Ai 12/1/2014 3194 31 87363 2818 F30i 1/1/2014 0 0 0 0 F30i 2/1/2014 0 0 0 0 F30i 3/1/2014 0 0 0 0 F30i 4/1/2014 0 0 0 0 F30i 5/1/2014 0 0 0 0 F42i 1/1/2014 2900 31 79362 2560 F42i 2/1/2014 2926 28 72065 2574 F42i 3/1/2014 2885.806 31 75177.66 75178 F42i 4/1/2014 2807.867 30 64984.26 2166.142 F42i 5/1/2014 2581.484 31 57606.17 1858.263 F42i 6/1/2014 2543.067 30 57124.01 1904.134 F42i 7/1/2014 2651 31 73610 2375 F42i 8/1/2014 2393 31 49960 1612 F42i 9/1/2014 2104 30 30939 1031 F42i 10/1/2014 1865 31 32413 1046 F42i 11/1/2014 0 0 0 0 F42i 12/1/2014 1954 26 62751 2413 F46i 1/1/2014 0 0 0 0 F46i 2/1/2014 0 0 0 0 F46i 3/1/2014 0 0 0 0 F46i 4/1/2014 0 0 0 0 F46i 5/1/2014 0 0 0 0 F46i 6/1/2014 0 0 0 0 F46i 7/1/2014 539 1 2050 2050 F46i 8/1/2014 806 31 47978 1548 F46i 9/1/2014 805 30 26232 874 F46i 10/1/2014 825 31 28250 911 F46i 11/1/2014 913 30 30553 1018 F46i 12/1/2014 974 31 31178 1006 F49i 1/1/2014 0 0 0 0 F49i 2/1/2014 0 0 0 0 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) F49i 3/1/2014 0 0 0 0 F49i 4/1/2014 0 0 0 0 F49i 5/1/2014 0 0 0 0 F49i 6/1/2014 0 0 0 0 F49i 7/1/2014 0 0 0 0 F49i 8/1/2014 0 0 0 0 F49i 9/1/2014 0 0 0 0 F49i 10/1/2014 656 21 19993 952 F49i 11/1/2014 772 30 36625 1221 F49i 12/1/2014 880 31 37924 1223 F62i 1/1/2014 2239 31 61465 1983 F62i 2/1/2014 2166 28 58216 2079 F62i 3/1/2014 817.2258 31 44843.35 44843 F62i 4/1/2014 943.3667 30 50870.7 1695.69 F62i 5/1/2014 616.0323 31 40472.84 1305.576 F62i 6/1/2014 740.2333 30 40355.02 1345.167 F62i 7/1/2014 1694 30 55539 1851 F62i 8/1/2014 1311 31 50011 1613 F62i 9/1/2014 1271 30 47420 1581 F62i 10/1/2014 1742 31 57319 1849 F62i 11/1/2014 2397 30 64281 2143 F62i 12/1/2014 2379 31 65888 2125 F70Ai 5/1/2014 1513.345 29 70084.64 2416.712 F70Ai 6/1/2014 1704.133 30 82725.33 2757.511 F70Ai 7/1/2014 1861 31 95637 3085 F70Ai 8/1/2014 1611 31 72130 2327 F70Ai 9/1/2014 1554 30 59082 1969 F70Ai 10/1/2014 1721 31 97433 3143 F70Ai 11/1/2014 1836 30 77992 2600 F70Ai 12/1/2014 1994 31 108181 3490 F70i 1/1/2014 0 0 0 0 F70i 2/1/2014 0 0 0 0 F70i 3/1/2014 0 0 0 0 F70i 4/1/2014 1339 9 20175.13 2241.681 F73Ai 1/1/2014 0 0 0 0 F73Ai 2/1/2014 0 0 0 0 F73Ai 3/1/2014 0 0 0 0 F73Ai 4/1/2014 0 0 0 0 F73Ai 5/1/2014 0 0 0 0 F73Ai 6/1/2014 0 0 0 0 F73Ai 7/1/2014 0 0 0 0 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) F73Ai 8/1/2014 0 0 0 0 F73Ai 9/1/2014 0 0 0 0 F73Ai 10/1/2014 0 0 0 0 F73Ai 11/1/2014 0 0 0 0 F73Ai 12/1/2014 0 0 0 0 F74Ai 5/1/2014 800 2 1332.266 666.133 F74Ai 6/1/2014 783.8214 28 20049.35 716.0482 F74Ai 7/1/2014 545 27 46576 1725 F74Ai 8/1/2014 134 31 43058 1389 F74Ai 9/1/2014 1700 30 34505 1150 F74Ai 10/1/2014 1700 31 42837 1382 F74Ai 11/1/2014 1700 30 50234 1674 F74Ai 12/1/2014 1700 31 51608 1665 F74i 1/1/2014 0 0 0 0 F74i 2/1/2014 0 0 0 0 F74i 3/1/2014 0 0 0 0 F74i 4/1/2014 0 0 0 0 F74i 5/1/2014 0 0 0 0 F82Ai 1/1/2014 3446 31 20706 668 F82Ai 2/1/2014 3460 28 18885 674 F82Ai 3/1/2014 3453.516 31 19910.98 19911 F82Ai 4/1/2014 3425.87 23 14426.37 627.2333 F82Ai 5/1/2014 3309.28 25 17586.05 703.442 F82Ai 6/1/2014 3433.367 30 16697.32 556.5773 F82Ai 7/1/2014 3430 31 18890 609 F82Ai 8/1/2014 3434 31 19290 622 F82Ai 9/1/2014 3413 30 18974 632 F82Ai 10/1/2014 3402 31 19065 615 F82Ai 11/1/2014 3391 30 18604 620 F82Ai 12/1/2014 3415 31 19950 644 F83i 1/1/2014 0 0 0 0 F83i 2/1/2014 0 0 0 0 F83i 3/1/2014 0 0 0 0 F83i 4/1/2014 0 0 0 0 F83i 5/1/2014 0 0 0 0 F83i 6/1/2014 0 0 0 0 F83i 7/1/2014 0 0 0 0 F83i 8/1/2014 0 0 0 0 F83i 9/1/2014 1444 30 31605 1054 F83i 10/1/2014 1549 28 29346 1048 F83i 11/1/2014 0 0 0 0 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) F83i 12/1/2014 0 0 0 0 1`8413i 1/1/2014 2109 31 113162 3650 F84Bi 2/1/2014 2206 28 99034 3537 F84Bi 3/1/2014 2250.935 31 104906.8 104907 F84Bi 4/1/2014 2185.467 30 84359.71 2811.99 F84Bi 5/1/2014 1997.419 31 60148.12 1940.262 F8413i 6/1/2014 1565.4 30 30349.75 1011.658 F8413i 7/1/2014 1430 31 26775 864 F8413i 8/1/2014 1369 31 29363 947 F846i 9/1/2014 1252 30 24591 820 F8413i 10/1/2014 1233 31 27160 876 F8413i 11/1/2014 1130 30 21950 732 F84Bi 12/1/2014 1112 31 25991 838 F85i 1/1/2014 3215 31 58760 1895 F85i 2/1/2014 3232 28 52948 1891 F85i 3/1/2014 3229.065 31 58536.65 58537 F85i 4/1/2014 3183.467 30 54313.29 1810.443 F85i 5/1/2014 3127.323 31 56163.38 1811.722 F85i 6/1/2014 3072.667 30 51639.85 1721.328 F85i 7/1/2014 3055 31 55056 1776 F85i 8/1/2014 2822 31 48439 1563 F85i 9/1/2014 2906 30 52262 1742 F85i 10/1/2014 3003 31 56537 1824 F85i 11/1/2014 3067 30 55294 1843 F85i 12/1/2014 3084 31 57533 1856 F88i 1/1/2014 0 0 0 0 F88i 2/1/2014 0 0 0 0 F88i 3/1/2014 710.25 28 58065.63 58066 F88i 4/1/2014 514.5 30 38850.41 1295.014 F88i 5/1/2014 576.7742 31 45823.76 1478.186 F88i 6/1/2014 526.1667 30 40616.74 1353.891 F88i 7/1/2014 673 30 50567 1686 F88i 8/1/2014 570 31 41910 1352 F88i 9/1/2014 604 30 46599 1553 F88i 10/1/2014 615 31 49613 1600 F88i 11/1/2014 589 30 46048 1535 F88i 12/1/2014 623 31 49901 1610 F89i 1/1/2014 0 0 0 0 F89i 2/1/2014 0 0 0 0 F89i 3/1/2014 0 0 0 0 F89i 4/1/2014 0 0 0 0 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) F89i 5/1/2014 0 0 0 0 F89i 6/1/2014 0 0 0 0 F89i 7/1/2014 1700 27 41470 1536 F89i 8/1/2014 2042 31 38398 1239 F89i 9/1/2014 2685 30 49937 1665 F89i 10/1/2014 2792 31 47811 1542 F89i 11/1/2014 2589 30 36720 1224 F89i 12/1/2014 2521 31 37579 1212 F90i 1/1/2014 0 0 0 0 F90i 2/1/2014 0 0 0 0 F90i 3/1/2014 0 0 0 0 F90i 4/1/2014 0 0 0 0 F90i 5/1/2014 0 0 0 0 F90i 6/1/2014 0 0 0 0 F90i 7/1/2014 0 0 0 0 F90i 8/1/2014 0 0 0 0 F90i 9/1/2014 0 0 0 0 F90i 10/1/2014 0 0 0 0 F90i 11/1/2014 0 0 0 0 F90i 12/1/2014 0 0 0 0 F91i 1/1/2014 2067 31 53854 1737 F91i 2/1/2014 2102 28 48387 1728 F91i 3/1/2014 2101.355 31 52257.37 52257 F91i 4/1/2014 1901.433 30 39341.39 1311.38 F91i 5/1/2014 1883 31 41573.43 1341.079 F91i 6/1/2014 1987.433 30 44627.31 1487.577 F91i 7/1/2014 2063 31 48903 1578 F91i 8/1/2014 1885 31 34287 1106 F91i 9/1/2014 1845 30 35019 1167 F91i 10/1/2014 1769 31 32750 1056 F91i 11/1/2014 1949 30 42435 1414 F91i 12/1/2014 2004 31 44601 1439 F92i 1/1/2014 3225 31 41052 1324 F92i 2/1/2014 3245 28 36403 1300 F92i 3/1/2014 3292.29 31 42228.75 42229 F92i 4/1/2014 3283.522 23 29667.59 1289.895 F92i 5/1/2014 3074.36 25 35817.75 1432.71 F92i 6/1/2014 3241.567 30 40877.27 1362.576 F92i 7/1/2014 3169 31 37013 1194 F92i 8/1/2014 3088 31 29736 959 F92i 9/1/2014 3048 30 34126 1138 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) F92i 10/1/2014 3003 31 35274 1138 F92i 11/1/2014 2923 30 21993 733 F92i 12/1/2014 2903 31 34044 1098 F95i 1/1/2014 0 0 0 0 F95i 2/1/2014 0 0 0 0 F95i 3/1/2014 724.25 4 6461.236 6461 F95i 4/1/2014 1015.5 30 65064.26 2168.809 F95i 5/1/2014 1129.194 31 49939.35 1610.947 F95i 6/1/2014 1275.3 30 53560.32 1785.344 F95i 7/1/2014 1444 31 60545 1953 F95i 8/1/2014 1286 31 43553 1405 F95i 9/1/2014 1385 30 47389 1580 F95i 10/1/2014 1137 31 32452 1047 F95i 11/1/2014 0 0 0 0 F95i 12/1/2014 1158 27 51464 1906 F99i 1/1/2014 3485 31 31284 1009 F99i 2/1/2014 3499 28 28399 1014 F99i 3/1/2014 3499.968 31 31441.03 31441 F99i 4/1/2014 3393.158 19 18442.86 970.6769 F99i 5/1/2014 0 0 0 0 F99i 6/1/2014 0 0 0 0 F99i 7/1/2014 0 0 0 0 F99i 8/1/2014 0 0 0 0 F99i 9/1/2014 0 0 0 0 F99i 10/1/2014 1878 16 11965 748 F99i 11/1/2014 2221 30 20369 679 F99i 12/1/2014 2599 31 24711 797 H06i 1/1/2014 1565 31 83500 2694 H06i 2/1/2014 1547 28 75396 2693 H06i 3/1/2014 1567.258 31 87228.61 87229 H06i 4/1/2014 1567.333 30 83629.76 2787.659 H06i 5/1/2014 1554.516 31 88979.09 2870.293 H06i 6/1/2014 1543 30 85750.62 2858.354 H06i 7/1/2014 1521 30 85109 2837 H06i 8/1/2014 1503 31 82914 2675 H06i 9/1/2014 1511 30 81061 2702 H06i 10/1/2014 1523 31 85001 2742 H06i 11/1/2014 1495 30 79898 2663 H06i 12/1/2014 1499 31 83041 2679 J11i 1/1/2014 2395 31 42428 1369 Ali 2/1/2014 2374 28 34494 1232 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) J11i 3/1/2014 2440.258 31 47012.91 47013 J11i 4/1/2014 2397.167 30 34174.89 1139.163 J11i 5/1/2014 2424 31 43137.74 1391.54 J11i 6/1/2014 2403.2 30 39188.86 1306.295 J11i 7/1/2014 2352 30 40688 1356 J11i 8/1/2014 2555 31 49781 1606 J11i 9/1/2014 2499 30 41674 1389 J11i 10/1/2014 2512 31 44676 1441 J11i 11/1/2014 2396 29 34401 1186 J11i 12/1/2014 2470 31 38869 1254 J13i 1/1/2014 1997 31 38896 1255 J13i 2/1/2014 1915 28 29341 1048 J13i 3/1/2014 1905.387 31 35886.24 35886 J13i 4/1/2014 1953.7 30 39698.17 1323.272 J13i 5/1/2014 1927.065 31 39134.09 1262.39 J13i 6/1/2014 1917.4 30 37331.61 1244.387 J13i 7/1/2014 1829 30 33400 1113 J13i 8/1/2014 1885 31 36889 1190 J13i 9/1/2014 1844 30 33265 1109 J13i 10/1/2014 1819 31 36124 1165 J13i 11/1/2014 1800 30 30902 1030 J13i 12/1/2014 1894 31 37452 1208 J18i 1/1/2014 1206 30 19034 634 J18i 2/1/2014 1316 26 17862 687 J18i 3/1/2014 1177.935 31 24973.94 24974 J18i 4/1/2014 1245.739 23 21093.74 917.1193 J18i 5/1/2014 0 0 0 0 J18i 6/1/2014 0 0 0 0 J18i 7/1/2014 1136 11 11210 1019 J18i 8/1/2014 1263 31 34759 1121 J18i 9/1/2014 1414 24 26144 1089 J18i 10/1/2014 770 5 1678 336 J18i 11/1/2014 875 28 9279 331 J18i 12/1/2014 897 30 10269 342 K21Ai 1/1/2014 1216 31 44857 1447 K21Ai 2/1/2014 1258 23 29219 1270 K21Ai 3/1/2014 448.05 20 17181.01 17181 K21Ai 4/1/2014 393.5714 14 11968.94 854.9245 K21Ai 5/1/2014 242.5 14 10457.05 746.932 K21Ai 6/1/2014 368.3 30 24093.09 803.103 K21Ai 7/1/2014 356 31 23098 745 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) K21Ai 8/1/2014 526 31 28635 924 K21Ai 9/1/2014 831 30 29795 993 K21Ai 10/1/2014 665 31 22945 740 K21Ai 11/1/2014 901 30 24173 806 K21Ai 12/1/2014 784 31 18592 600 K22i 1/1/2014 773 31 47322 1527 K22i 2/1/2014 887 23 31574 1373 K22i 3/1/2014 678.9 20 15997.6 15998 K22i 4/1/2014 822.0714 14 11432.37 816.5976 K22i 5/1/2014 416.9286 14 10665.53 761.8233 K22i 6/1/2014 518.5 30 24654.48 821.8158 K22i 7/1/2014 563 31 25505 823 K22i 8/1/2014 615 31 26630 859 K22i 9/1/2014 804 30 28621 954 K22i 10/1/2014 796 31 24581 793 K22i 11/1/2014 901 30 25547 852 K22i 12/1/2014 838 31 22550 727 K43i 1/1/2014 0 0 0 0 K43i 2/1/2014 0 0 0 0 K43i 3/1/2014 0 0 0 0 K43i 4/1/2014 269.4 5 4403.761 880.7521 K43i 5/1/2014 796.5 14 14201.11 1014.365 K43i 6/1/2014 1223.533 30 35345.09 1178.17 K43i 7/1/2014 1525 31 37208 1200 K43i 8/1/2014 1614 31 37994 1226 K43i 9/1/2014 1634 30 36632 1221 K43i 10/1/2014 1627 31 36057 1163 K43i 11/1/2014 1638 30 34620 1154 K43i 12/1/2014 1658 31 36483 1177 L08i 1/1/2014 0 0 0 0 L08i 2/1/2014 0 0 0 0 L08i 3/1/2014 0 0 0 0 L08i 4/1/2014 2127 12 10501.61 875.1345 L08i 5/1/2014 2415.677 31 28643.48 923.9831 1-08i 6/1/2014 2548.233 30 28891.48 963.0493 L08i 7/1/2014 2769 31 36482 1177 L08i 8/1/2014 2801 31 35206 1136 1-08i 9/1/2014 3014 30 41726 1391 1-08i 10/1/2014 2788 31 29993 968 L08i 11/1/2014 2436 30 19037 635 L08i 12/1/2014 2712 31 31574 1019 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Well L09Ai L09Ai L09Ai L09Ai L09Ai L09Ai L09Ai L09Ai 1-09i L09 i 1-09i 1-09i 1-09i L15i L15i L15i L15i L15i L15i L15i L15i L15i L15i L15i L15i L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L16Ai L24i L24i L24i L24i Month 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 WH Pressure Avg (psi) 1581.421 1768.833 1906 1770 2061 2109 2269 2313 0 0 0 305 0 1837 1998 1872.065 1648.367 1485.323 1411.733 1540 1682 1676 1788 1662 1640 1831 1160 1520.677 1545.533 1522 1570.767 1415 1167 1284 1371 1394 1135 0 0 0 0 Days Operating 19 30 31 31 30 31 30 31 0 0 0 1 0 31 28 31 30 31 30 31 31 30 31 30 31 16 16 31 30 31 30 31 31 30 31 30 31 0 0 0 0 Inj Vol Calc. (BBL, MCF) 23148.27 40111.25 46449 34436 43468 41683 48965 46618 0 0 0 1891.874 0 31084 34742 30480.73 23260.15 21071.49 19424.64 26856 29504 28281 33595 26682 29343 57552 42838 101561.8 86332.84 88564.16 86023.25 74337 59972 66234 71506 70613 57988 0 0 0 0 Injection Rate Avg. (BWPD) 1218.33 1337.042 1498 1111 1449 1345 1632 1504 0 0 0 1891.874 0 1003 1241 30481 775.3384 679.7254 647.488 866 952 943 1084 889 947 3597 2677 101562 2877.761 2856.908 2867.442 2398 1935 2208 2307 2354 1871 0 0 0 0 Exhibit 2-F Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) L24i 5/1/2014 0 0 0 0 L24i 6/1/2014 0 0 0 0 L24i 7/1/2014 0 0 0 0 L24i 8/1/2014 0 0 0 0 L24i 9/1/2014 0 0 0 0 1-24i 10/1/2014 1646 20 22278 1114 L24i 11/1/2014 2008 30 36056 1202 L24i 12/1/2014 2181 31 37331 1204 L32i 1/1/2014 3372 31 41020 1323 L32i 2/1/2014 3410 28 36473 1303 L32i 3/1/2014 3388.129 31 38340.96 38341 L32i 4/1/2014 3248.333 30 29858.71 995.2902 1-32i 5/1/2014 3052.161 31 25153.99 811.4191 L32i 6/1/2014 2931.667 30 21941.72 731.3907 L32i 7/1/2014 2926 31 26242 847 L32i 8/1/2014 3009 31 29156 941 L32i 9/1/2014 3015 30 28012 934 L32i 10/1/2014 2958 31 27686 893 L32i 11/1/2014 2967 30 28736 958 L32i 12/1/2014 2974 31 30499 984 L33i 1/1/2014 2897 31 121859 3931 L33i 2/1/2014 3011 28 115137 4112 1-33i 3/1/2014 3019.161 31 122571.8 122572 L33i 4/1/2014 3010.133 30 107540.4 3584.679 L33i 5/1/2014 2868.452 31 96095.64 3099.859 L33i 6/1/2014 2802.533 30 83255.07 2775.169 1-33i 7/1/2014 2976 31 99226 3201 L33i 8/1/2014 2622 31 70165 2263 L33i 9/1/2014 2877 30 91645 3055 L33i 10/1/2014 2928 31 100601 3245 L33i 11/1/2014 2848 30 90775 3026 L33i 12/1/2014 2898 31 99717 3217 L39i 9/1/2014 0 0 0 0 L39i 10/1/2014 0 0 0 0 Section 3 Schrader Bluff Oil Pool List of Exhibits Total Reservoir Production Plot 3-A Total Reservoir Injection Plot 3-B Pertinent Data Summary 3-C Reservoir Voidage Balance 3-D Static Pressure Data 3-E Injection Rate & Pressure Data By Well 3-F Daily Allocation Factors 3-G Schrader Bluff Oil Pool Waterflood Project Summary The Schrader Bluff Oil Pool waterflood area is shown in Exhibit 3-A. The locations of producing and injecting wells are shown, as are the interpreted hydraulic units. Each hydraulic unit represents regions of the reservoir that are believed to be hydraulically isolated due to faulting and/or lithologic controls. There were 37 producing wells and 33 injection wells active during 2014.' Exhibit 3-A shows a production plot for the Schrader Bluff reservoir covering the entire project history through December 2014. The Schrader Bluff Oil Pool oil production averaged 6.3 MSTBD for 2014 compared to 5.7 MSTBD in 2013. This represents an oil production increase of 10.5% in 2014. Gas production averaged at 2.6 MMSCFD in 2014 compared to 2.4 MMSCFD in 2013. Representing a gas production increase of 8.3% in 2014. Water production averaged 10.9 MBWD in 2014 compared to 10.3 MBWD in 2013. Cumulative production since waterflood startup through the end of 2014 is 72.8 MMSTB of oil, 42.4 BSCF of gas, and 65.6 MMSTB of water. Exhibit 3-13 shows an injection plot for the Schrader Bluff reservoir covering the entire project history through December 2014. The water injection rate averaged 22.1 MB WD for 2014 compared to 20.6 MBWD in 2015. Cumulative water injection since waterflood startup through the end of 2014 is 157.8 MMSTB. Gas injection in the Schrader began in 2006 and continued through December 2008. Of the two patterns utilized for the WAG pilot, only the MPE-29 (injector) to MPE-24A (producer) pattern demonstrated signs of WAG interactions as characterized by the GOR response at the producer. No gas was injected in 2009 to 2014. Cumulative gas injection through the end of 2014 remains as it was at year-end 2008: 220 MMSCF. As of December 2014 the cumulative under injection is 28.5 MMM. In the supported waterflood patterns, under -injection is minimal. The average voidage replacement ratio, or VRR, for 2014 was 1.26, an increase compared to the 2013 VRR of 1.13. Water cut slightly decreased from 64.2% in 2013 to 63.5% in 2014. GOR was up slightly from 413 SCF/STB in 2013 to 423 SCF/STB in 2014. Exhibit 3-C is a summary of the pertinent production information for the Schrader Bluff Oil Pool in 2014. Future development plans for the Schrader Bluff oil pool include infill and pattern redevelopment in the S -pad and Tract 14 areas, potential expansion into undeveloped areas in the North West area of the pool, and the evaluation of EOR techniques suitable for Viscous Oil application. The first drilling target in 2015 will be from L -pad in Northwest Schrader O -sands. ' Note that the count of 33 injectors counts wells with a long string and short string dual completion as a single well. If long strings and short strings within a well were counted separately, there would be 46 active injectors. Exhibit 3-D shows a monthly breakdown of production and injection data for the report period. Exhibit 3-E presents the reservoir pressure data for the Schrader Bluff wells taken during 2014. In 2014, 41 static pressures were obtained, 10 from injectors (dual string counted separately) and 31 from producers. Exhibit 3-F provides a monthly summary of individual well injection rate and injection pressure data for all of the Schrader Bluff Oil Pool injectors. Exhibit 3-G provides daily oil, gas, and water allocation factors for the Milne Point facility for 2014. As the Milne Schrader reservoir shares surface flowlines and its processing facility with the Milne Kuparuk, Sag, and Ugnu Producing Areas, all allocation factors are calculated on a field level based on oil sales rate and are back allocated in proportion to the sum of the test rates for online wells. The average field oil allocation factor for 2014 was 0.87. This is a slight decrease from the 2013 average of 0.90. For 2014, the water allocation factor averaged 1.12, and the gas allocation factor was 1.14. The water allocation factor remained the same as the 2013 average and the gas allocation factor improved, but changed from under -allocated to over -allocated, compared to 2013's average of 1.14. Exhibit 3-A Hilcorp Alaska - Milne Point Unit Schrader Reservoir, Total Production 10 0 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 t Water Cut %, SBL t Producers Online —H — Gas/Oil Ratio SBL 1.0 0.9 0.8 0.7 0.6 0 0.5 a 0 0.4 0 0.3 0.2 0.1 0.0 _ i 111111 •1111NINON MINION II � !� I �1Lr •, iii '�iS�1 RJR!�i���i�:'�'��31�1 ii� FT.'�1�iiliiiii►�ii����1 . 1111 111 AIA 1111 11 1111 �1iiiii„';���I�:. .].i►"}I�it�������' • • • • •• • •• 11 1 1 NICE, 1 1• 1 1: 1•m[ems 10 0 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 t Water Cut %, SBL t Producers Online —H — Gas/Oil Ratio SBL 1.0 0.9 0.8 0.7 0.6 0 0.5 a 0 0.4 0 0.3 0.2 0.1 0.0 II � !� I �1Lr •, iii '�iS�1 RJR!�i���i�:'�'��31�1 ii� 10 0 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 t Water Cut %, SBL t Producers Online —H — Gas/Oil Ratio SBL 1.0 0.9 0.8 0.7 0.6 0 0.5 a 0 0.4 0 0.3 0.2 0.1 0.0 1000000 100000 Q m U) 10000 Exhibit 3-13 Hilcorp Alaska - Milne Point Unit Schrader Reservoir, Total Injection C 0 1000 v m c d 100 10000000 1000000 io DW LL N 100000 2 a LL N N �C � C C 10000 d 'e A"> � o N 1000 10 4— I I I I i I I I I I I 4 i Ili—I I I I I i I' 100 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 Water Inj Cum SBL Water Inj Rate SBL -Gas Inj Cum SBL - * Gas Inj Rate SBL Solvent Inj Cum SBL t Solvent Inj Rate SBL 60 .._.. 50 I i s m 40 �, r c • J O 30 - 0 v m • 'c w 0 20 �f 10 -TT 0 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 Water Injectors On Line 0 Gas Injectors On Line 0 MI Injectors OnLine Exhibit 3-C Milne Point Unit - Schrader Bluff Oil Pool SUMMARY OF PERTINENT DATA As of December 31, 2014 WATERFLOOD START-UP DATE: March 1992 PRODUCTION Prior to Waterflood Start -Up: Oil (MSTB) 902 Gas (MMSCF) 303 Water (MSTB) 136 Since Waterflood Start -Up: Oil (MSTB) 71,880 Gas (MMSCF) 42,680 Water (MSTB) 65,460 FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB) 157,680 Injection Gas (MMSCF) 220 Lean Gas (MMSCF) 220 Solvent (MMSCF) 0 AVERAGE OF PRESSURES OBTAINED IN 2014 Cad 7.000' TVD ss December, 2014 Pressure (psig) 1,736 WELL COUNT (Wells in Operation)* Production Wells 37 WAG Injection 0 Water Only Injection 46 Gas Only Injection 0 Notes: ' Reflects ONLY operable wells. Exhibit 3-D RESERVOIR VOIDAGE BALANCE Milne Point Unit Schrader Bluff Oil Pool January - December 2014 Production: Injection: Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage Month Prod Rate Prod Rate Prod Rate Voidage Inj Rate Inj Rate Replacement Replacement Balance (stb/day) (stb/day) (mscf/day) (rbbl/day) (stb/day) (mscf/day) (rbbl/day) Ratio (rbbl/day) 1/31/2014 6,533 11,761 2,322 20,357 24,016 0 24,256 1.19 3,899 2/28/2014 6,201 11,322 2,769 20,281 22,785 0 23,013 1.13 2,732 3/31/2014 6,351 11,581 2,680 20,537 22,833 0 23,061 1.12 2,525 4/30/2014 6,299 12,449 2,842 21,600 25,399 0 25,653 1.19 4,053 5/31/2014 6,593 10,927 3,014 20,540 23,875 0 24,113 1.17 3,573 6/30/2014 6,164 11,420 2,930 20,579 22,701 0 22,928 1.11 2,349 7/31/2014 5,943 10,109 2,478 18,439 21,715 0 21,932 1.19 3,493 8/31/2014 5,973 10,270 2,236 18,283 19,156 0 19,348 1.06 1,064 9/30/2014 6,446 11,458 2,417 20,116 20,072 0 20,273 1.01 157 10/31/2014 5,857 10,300 2,342 18,371 16,902 0 17,071 0.93 -1,300 11/30/2014 6,809 9,468 2,891 19,064 20,266 0 20,469 1.07 1,404 12/31/2014 6,008 10,212 2,686 19,171 25,455 0 25,709 1.34 6,538 Average: 2014 6,265 10,940 2,651 19,778 22,098 0 22,319 1.13 2,541 Cumulative: mstb mstb mmscf mrb mstb mmscf mrb mrb 31 -Dec -14 72,782 65,596 42,983 184,876 157,680 220 159567 0.86 -25,309 Page 1 Exhibit 3-E Static Pressure Data Schrader Bluff Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Oprt,rHilwrp Alaska, LLC. 12. Address: 3800 Cent Int Dr, Anchomste AK 99503 3. Una or Lease Name: Milne Point 14. Field and Pool: Schroder Bluff Pool 5. Datum Reference: 4000' SS 6. Oil Grav : API - 14-22 7. Gas G-, Air = 0.65 8. Well Name and Number 9. API Number 50-xXx-%xxxx-xx-xx 10. Oil (0) 11. or Gas (G) AOGCC Pool Code 12. Final Test Data 13, Shut -In Time, Hours 14. Press. S_ Type (see Insirudbns (or odea) 15. B.H. 16. Depth Tool Temp. ND. 17. Final P. re al Tool Depth 18. Datum TVD. (input) 19. Pressure 20. Comments Grodlent, psVll. Pressure at Datum (cal) Zone MPB-27 50-500-29232-33-00 INJ 525140 9/29/2014 SBHP 73 4,000 1,819 4000 0.625 1,819 TVD/SS=TVD MPC -41 50-500-29230-14-00 INJ 525140 5/20/2014 45,109 SBHP 88 3,801 1593 4000 0.518 1,698 Grad -0.534 Psifft. MPC -41 50-500-29230-14-00 INJ 525140 1/20/2014 42,211 SBHP 68 3388 1,674 4000 0.047 1,703 Grad =0.0475 psilft OA MPE-15 50-500-29225-28-00 PROD 525140 2/11/2014 1,920 PP 0 4,075 1,535 4000 0.438 1,502 Grad =0.44 psilft NB+OA MPE-24A 50-500-29228-67-01 PROD 525140 5/27/2014 7,462 SBHP 81 4,027 1,676 4000 0.433 1,664 MPE-24A 50-50029228-67-01 PROD 525140 3/30/2014 6,087 SBHP 75 3,644 1,532 4000 0.294 1.637 Grad - 0.44 sift. MPE-24A 50-500-2922"7-01 PROD 525140 3/31/2014 6,107 SBHP 84 4,144 1,704 4000 0.352 1,653 MPE-32 50-500-29232-61-00 PROD 525140 3/13/2014 1,536 PP 0 4,333 1,187 4000 0.439 1,041 Grad = 0.44 sift OA+NC+ND MPG -13 50-500-29227-82-00 INJ 525140 10/8/2014 3,696 SBHP 77 3 885 2 613 4000 0.435 Data from PFO which confirms 2,663 influence from offsets in HU7 MPG -16 50-500-29231-89-00 PROD 525140 2/1/2014 2,040 PP 0 4 153 1 385 4000 0.437 1,318 Grad = 0.44 PsVft OA+013 MPG -18 50-500-29231-94-00 PROD 525140 2/9/2014 1,416 PP 0 3,863 1,823 4000 0.437 1,883 Grad = 0.44 psVft OA+OB MPG -18 50-50029231-94-00 PROD 525140 3/14/2014 4,368 SBHP 0 4,106 1,995 4000 0.442 1,948 Grad =0.44 psitft OB MPG -18 50-500-29231-94-00 PROD 525140 3/14/2014 792 PP 0 3,863 1,510 4000 0.437 1,570 Grad = 0.44 DsVft OA MPH -12 50-500-29228-07-00 INJ 525140 8/5/2014 597 SBHP 73 4.000 2,218 4000 0.500 2,218 NS MPH -13A 50-5 0029 22 8-1 8-01 Unknow n Type 525140 7/2/2014 22,800 PP 0 3,860 1,098 4000 0.437 1,159 Grad = 0.44 sl/ft NB MPH -19 50-500-29233-71-00 PROD 525140 4/12/2014 408 PP 0 3917 1559 4000 0.435 Grad = 0.44 psi/ft. Still gaining 3 1,595 psilday OA MPI-02LS 50-500-29220-66-80 INJ 525140 3/26/2014 104,989 SBHP 76 3130 2,722 4000 1.987 3,060 MPI -03 50-500-29220-67-00 PROD 525140 1/10/2014 552 PP 0 3,582 1,11 4000 0.440 Grad = 0.44 psi/ft. Still gaining 2 1,299 psilday NA+NB+NC+NE+ OA+OB MPI -04A 50-500-29220-68-01 PROD 525140 1/11/2014 16,345 SBHP 73 3,484 1,359 4000 0.389 1,560 Grad = 0.39 sift NA+NB+NC+OA+ OB MPI -04A 50-500-29220-68-01 PROD 525140 1/11/2014 16,344 SBHP 68 3,217 1,255 4000 0.389 1,560 NA+NB+NC+OA+ OB MPI -07 50-500-29226-02-00 PROD 525140 6/23/2014 816 PP 0 3,465 1,285 4000 0.440 1.520 Grad=0.44 sift NB+OA+OB MPI -11 50-500-29230-33-00 PROD 525140 7/2/2014 33,288 PP 0 3,484 1,646 4000 0.440 1873 Gradsift OA+OB MPI -12 50-500-29230-38-00 PROD 525140 10/10/2014 2,302 SBHP 48 2,515 1,146 4000 0.438 1,797 Grad 0.4384psi/ft MPI -12 50-500-29230-38-00 PROD 525140 7/2/2014 1752 PP 0 3,535 1059 4000 0.441 1264 Grad=0.44 sUft OA+OB MPI -12 50-5002923038-00 PROD 525140 11/13/2014 3,129 SBHP 50 2,515 1,227 4000 0.438 1678 Grad=0.4384 Uft MPI -15 50-500-29231-06-00 PROD 525140 3124/2014 26.079 SBHP 72 3,626 1,521 4000 0.406 1673 MPI -15 50-500-29231-06-00 PROD 525140 3/25/2014 26103 SBHP 73 3,626 1,517 4000 0.402 1,668 Grad -0.4019 sl/ft. MPJ -05 50-500-29221-96-00 PROD 525140 7/2/2014 12,000 PP 0 3,689 1,375 4000 0.441 1,512 Grad = 0.44 sift NA+NB+NC+NE+ OA+OB MPJ -18 50-500-29228-34-00 INJ 525140 1/20/2014 1,632 S8HP 82 4,062 2,272 4000 0.434 2,245 SPMG Data OB MPJ -26 50-500-29232-05-00 PROD 525140 1/12/2014 SBHP 76 3,782 1,480 4000 0.391 1,565 NB+OA+OB MPJ -26 50-500-29232-05-00 PROD 525140 1/12/2014 9,716 SBHP 76 3,782 1,480 4000 0.386 1,564 Grad =0.39 sift NB+OA+OB MPJ -26 50-500-29232-05-00 PROD 525140 1/12/2014 SBHP 71 3,534 1,384 4000 0.390 1,566 NB+OA+08 MPJ -26 50-50029232-05-00 PROD 525140 1/12/2014 SBHP 71 3,534 1,384 4000 0.390 1,566 NB+OA+08 MPS -03 50-500-29231-05-00 PROD 525140 5/14/2014 17,275 SBHP 75 4008 1,599 4000 0.443 1,595 MPS -04 50-50029231-48-00 INJ 525140 9/8/2014 822 SBHP 86 4,000 2,390 4000 0.429 2,390 MPS -10A 50-50029231-52-01 INJ 525140 8/31/2014 SBHP 79 4,000 1,359 4000 0.417 1,359 TVD/SS=TVD MPS-16SS 50-50029231-51-81 INJ 525140 7/26/2014 941 SBHP 90 4,001 2,468 4000 0.397 2,467 NB MPS -24 50-500-29231-42-00 PROD 525140 7/2/2014 9,984 PP 0 3,883 2,396 4000 0.436 2,447 lGrad=0.44 psifft NB MPS -27 50-500-29230-84-00 PROD 525140 7/2/2014 40200 PP 0 3,932 1623 4000 0.442 1,653 Grad=0.44 sift OA MPS -32 50-50029231-57-00 PROD 525140 7/212014 28704 PP 0 3754 1583 4000 0.439 1691 Grad=0.44 sift NB MPS -34 50-50029231-71-00 PROD 525140 6/2212014 7437 SBHP 74 3,820 1158 4000 0.423 1319 Avera 1,736 21. All tests re oded herein were made in accordance wfth thea licable rules, re ulatbns and instrudbnsof the Alaska Oil and Gas Conservation Commissbn. Exhibit 3-E Static Pressure Data Schrader Bluff Oil Pool B. We 11 Nama and 9. All Number 10.011(0) 11. AOGCC Pool 12. Fine' Test 13. Shut-in 14. Press. II.H_ 16. Depth Tool 1T. Final 19. Datum 19. Pressure M. Comments Zane Number: 5D-XXX-XXXXX-XX-XX or Gas (G) Code Dale Time, Hours surv. Type Temp. WD. Pressure at TVD. Grad ht, pevfl. Preswre el (see Tool Depth (Input) Datum (cal) instraoli. for codes) I thereby oetty that the foregoing is true and oorred to the best of my knowledge. signature me Reservoir En ineer Printed Name Anthony McConkey I Dale 1 6/30/2015 FL Fluid Level PBU Pressure Build Up PFO Pressure Fall Off PP Pump Pressure SBHP Shut -In Bottom Hole Pressure Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well 1302i 1302i 1302i 1302i 1302i 1302i 1302i 1302i 1302i 1302i 602i 1302i 13271 -Si 13271 -Si 13271 -Si B271 -Si 13271 -Si 13271 -Si 13271 -Si B27LSi 13271 -Si 13271 -Si 13271 -Si 13271 -Si B27SSi 627SSi 627SSi B27SSi B27SSi B27SSi B27SSi B27SSi B27SSi 627SSi 627SSi 627SSi C41 i C41 i C41 i C41 i C41 i Month 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 WH Pressure Avg (psi) 872.4516 892.7857 907.2333 987.6552 955.3548 938.4667 921.2903 853.3333 872.8667 829.1613 829.5667 829.3548 0 0 0 0 0 0 0 0 0 0 0 0 1039.226 1046.179 1059.29 1078.643 1103.6 1087.241 1077.903 1078.129 1105.552 1071.581 1082.633 1092.323 0 0 0 333.2609 768.0968 Days Operating 31 28 30 29 31 30 31 30 30 31 30 31 0 0 0 0 0 0 0 0 0 0 0 0 31 28 31 28 30 29 31 31 29 31 30 31 0 0 0 23 31 Inj Vol Calc. (BBL, MCF) 9021.308 8520.997 9000.516 8583.588 8777.982 8455.596 9761.319 9085.042 8825.106 8362.735 9159.527 7997.38 0 0 0 0 0 0 0 0 0 0 0 0 10771.67 8358.476 8669.869 6675.578 8568.307 8596.113 12374.16 12107.25 10697.98 10360.86 9441.556 11730.11 0 0 0 10827.32 27984.67 Injection Rate Avg. (BWPD) 291.0099 304.3213 300.0172 295.9858 283.1607 281.8532 314.8813 302.8347 294.1702 269.7656 305.3176 257.98 0 0 0 0 0 0 0 0 0 0 0 0 347.4733 298.517 279.6732 238.4135 285.6102 296.4177 399.1666 390.5564 368.896 334.2213 314.7185 378.3906 0 0 0 470.753 902.7312 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well C41 i C41 i C41 i C41 i C41 i E12i E12i E12i E12i E12i E12i E12i E12i E12i E12i E12i E12i E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13131 -Si E13BSSi E136SSi E136SSi E136SSi E13BSSi E136SSi E136SSi E13BSSi E13BSSi E13BSSi E13BSSi E13BSSi Month 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 WH Pressure Avg (psi) 984.5667 1225.533 1155.516 1198.133 1209.613 1107.714 0 1071.15 1116.167 876.5 743.0667 882.9355 1023.452 1060.133 1064.647 398.3333 407.0645 1166.387 1189.05 1087.286 945.8 654.5 0 0 0 0 0 0 0 750.9355 787.2143 803.3226 814.2667 754.5161 804.3 803.9032 803.129 840.2333 704.3226 742.0333 720.129 Days Operating 30 30 31 30 31 7 0 20 30 28 30 31 31 30 17 6 31 31 20 21 30 6 0 0 0 0 0 0 0 31 28 31 30 31 30 31 31 30 31 30 31 Inj Vol Calc. (BBL, MCF) 29616.78 30155.49 19036.49 18053.03 16475.72 4081.631 0 7967.365 10557.15 8302.219 8079.282 12355.39 17513.11 16869.82 10931.42 1698.396 10053.88 11317.32 8800.791 10022.69 13205.49 3099.317 0 0 0 0 0 0 0 13021.08 18532.05 15029.67 14895.77 18386.12 15093.86 17680.71 17734.95 21185.05 20015.4 15195.93 18654.77 Injection Rate Avg. (BWPD) 987.2261 1005.183 614.0804 601.7676 531.4749 583.0901 0 398.3683 351.9051 296.5078 269.3094 398.5609 564.939 562.3272 643.0246 283.066 324.3189 365.0748 440.0395 477.2712 440.1828 516.5529 0 0 0 0 0 0 0 420.0349 661.8591 484.8281 496.5255 593.1007 503.1288 570.3454 572.0952 706.1685 645.6582 506.5308 601.7668 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) E29i 1/1/2014 0 0 0 0 E29i 2/1/2014 0 0 0 0 E29i 3/1/2014 0 0 0 0 E29i 4/1/2014 0 0 0 0 E29i 5/1/2014 0 0 0 0 E29i 6/1/2014 0 0 0 0 E29i 7/1/2014 0 0 0 0 E29i 8/1/2014 0 0 0 0 E29i 9/1/2014 0 0 0 0 E29i 10/1/2014 0 0 0 0 E29i 11/1/2014 779.5556 9 3866.427 429.603 E29i 12/1/2014 951.7419 31 15148.54 488.6626 G01i 1/1/2014 1011.839 31 33302.69 1074.28 G01i 2/1/2014 1031.321 28 30612.48 1093.303 G01i 3/1/2014 1027.097 31 32476.79 1047.638 G01i 4/1/2014 1028.7 30 33016.59 1100.553 G01i 5/1/2014 1011.355 31 32219.9 1039.351 G01i 6/1/2014 965.4545 22 24213.19 1100.599 G01i 7/1/2014 0 0 0 0 G01i 8/1/2014 0 0 0 0 G01i 9/1/2014 821.25 4 3841.926 960.4814 G01i 10/1/2014 910.7097 31 28713.97 926.2571 G01i 11/1/2014 942.0333 30 32726.94 1090.898 G01i 12/1/2014 949.9677 31 32112.45 1035.886 G03Ai 1/1/2014 1855.065 31 7500.3 241.9452 G03Ai 2/1/2014 1837.571 28 7297.063 260.6094 G03Ai 3/1/2014 2155.419 31 7821.029 252.2913 G03Ai 4/1/2014 2344.571 14 2420.635 172.9025 G03Ai 5/1/2014 0 0 0 0 G03Ai 6/1/2014 0 0 0 0 G03Ai 7/1/2014 0 0 0 0 G03Ai 8/1/2014 0 0 0 0 G03Ai 9/1/2014 0 0 0 0 G03Ai 10/1/2014 0 0 0 0 G03Ai 11/1/2014 0 0 0 0 G03Ai 12/1/2014 0 0 0 0 G05i 1/1/2014 0 0 0 0 G05i 2/1/2014 0 0 0 0 G05i 3/1/2014 0 0 0 0 G05i 4/1/2014 0 0 0 0 G05i 5/1/2014 0 0 0 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) G05i 6/1/2014 0 0 0 0 G05i 7/1/2014 0 0 0 0 G05i 8/1/2014 0 0 0 0 G05i 9/1/2014 0 0 0 0 G05i 10/1/2014 0 0 0 0 G05i 11/1/2014 0 0 0 0 G05i 12/1/2014 0 0 0 0 G07i 1/1/2014 1649.065 31 12252.19 395.2321 G07i 2/1/2014 1654.667 6 2396.132 399.3553 G07i 3/1/2014 0 0 0 0 G07i 4/1/2014 0 0 0 0 G07i 5/1/2014 2275.727 11 3091.93 281.0845 G07i 6/1/2014 2447.8 30 9570.752 319.0251 G07i 7/1/2014 2326.034 29 14800.84 510.3736 G07i 8/1/2014 1199.857 14 8836.588 631.1848 G07i 9/1/2014 1106.333 30 14378.36 479.2787 G07i 10/ 1/2014 1159.71 31 15607.57 503.47 G07i 11/1/2014 1190.133 30 15871.38 529.046 G07i 12/1/2014 1309.806 31 18001.43 580.6911 G081 1/1/2014 0 0 0 0 G081 2/1/2014 0 0 0 0 G081 3/1/2014 0 0 0 0 G081 4/1/2014 0 0 0 0 G081 5/1/2014 0 0 0 0 G081 6/1/2014 0 0 0 0 G081 7/1/2014 0 0 0 0 G081 8/1/2014 0 0 0 0 G081 9/1/2014 0 0 0 0 G081 10/1/2014 0 0 0 0 GO81 11/1/2014 0 0 0 0 G081 12/1/2014 0 0 0 0 G09i 1/1/2014 1045.839 31 11528.11 371.8744 G09i 2/1/2014 1072.857 28 10452.4 373.3001 G09i 3/1/2014 1036.419 31 10220.31 329.6874 G09i 4/1/2014 1111.633 30 16650.53 555.0175 G09i 5/1/2014 1163.387 31 21780 702.5806 G09i 6/1/2014 1069.897 29 10395.8 358.476 G09i 7/1/2014 1120.567 30 14375.25 479.1751 G09i 8/1/2014 1082.742 31 10069.04 324.8076 G09i 9/1/2014 1185.933 30 16703.27 556.7755 G09i 10/1/2014 1250.774 31 20493.76 661.0892 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well G09i G09i G10i G10i G10i G10i G10i G10i G10i G10i G10i G10i G10i G10i G13i G13i G13i G13i G13i G13i G13i G13i G13i G13i G13i G13i G17LSi G17LSi G17LSi G17LSi G17LSi G17LSi G17LSi G17LSi G17LSi G171 -Si G17LSi G171 -Si G17SSi G17SSi G17SSi Month 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 WH Pressure Avg (psi) 1170.6 1156.129 742.9032 740.6429 749.2581 788.9667 789.3636 0 0 0 670 728.7097 733.7333 739.0323 1102.097 1106.143 1110.065 1160.433 1095 0 0 0 0 958.1667 0 0 785.2258 783.5714 792 826.7 820.9677 841.0714 0 0 899 880.8667 899.8462 794 963.0323 969.2857 957.3333 Days Operating 30 31 31 28 31 30 22 0 0 0 22 31 30 31 31 28 31 30 7 0 0 0 0 6 0 0 31 28 31 30 31 28 0 0 5 30 26 2 31 28 30 Inj Vol Calc. (BBL, MCF) 9967.653 9105.249 20829.53 19024.56 19992.39 24568.23 17240.97 0 0 0 16830.4 26244.79 21178.19 20080.76 21069.51 15402.63 18094.59 27150.67 4425.528 0 0 0 0 4908.349 0 0 10530.18 8440.416 9135.017 12320.72 11770.18 9338.286 0 0 1777.902 13136.06 10028.07 247.5128 11863.19 10373.38 9447.842 Injection Rate Avg. (BWPD) 332.2551 293.7177 671.9204 679.4485 644.9158 818.9411 783.6803 0 0 0 765.0183 846.6063 705.9397 647.7666 679.6617 550.0939 583.6963 905.0224 632.2183 0 0 0 0 818.0581 0 0 339.6831 301.4434 294.678 410.6907 379.6833 333.5102 0 0 355.5804 437.8687 385.695 123.7564 382.6834 370.478 314.9281 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Inj Vol Calc. (BBL, MCF) 13265.09 9945.996 7123.116 0 0 2682.29 15186.02 12946.6 10907.68 5703.158 4971.07 6304.943 7235.821 7997.844 6249.969 8221.355 12091.22 11284.88 12446.74 10106.66 11905.74 0 0 0 0 0 0 0 0 0 0 0 0 7743.289 6470.289 7257.727 13951.5 12971.67 11034.46 4056.093 0 Injection Rate Avg. (BWPD) 442.1698 320.8386 296.7965 0 0 447.0484 506.2007 431.5533 363.5892 183.9728 177.5382 203.3853 241.194 257.995 208.3323 274.0452 390.0392 376.1628 401.5077 348.5057 384.056 0 0 0 0 0 0 0 0 0 0 0 0 249.7835 231.0818 241.9242 465.0501 418.4411 367.8153 368.7357 0 WH Pressure Well Month Avg (psi) Days Operating G17SSi 4/1/2014 993.7667 30 G 17SSi 5/1/2014 959.0323 31 G17SSi 6/1/2014 943.7083 24 G17SSi 7/1/2014 0 0 G17SSi 8/1/2014 0 0 G17SSi 9/1/2014 921.5 6 G17SSi 10/1/2014 999.9667 30 G17SSi 11/1/2014 973.4667 30 G17SSi 12/1/2014 948.1333 30 G19i 1/1/2014 1473.871 31 G19i 2/1/2014 1412.857 28 G19i 3/1/2014 1386.903 31 G19i 4/1/2014 2333.867 30 G19i 5/1/2014 2498.935 31 G19i 6/1/2014 2466.633 30 G19i 7/1/2014 2471.433 30 G19i 8/1/2014 2644.484 31 G19i 9/1/2014 2569.4 30 G19i 10/1/2014 2607.742 31 G19i 11/1/2014 2509.69 29 G19i 12/1/2014 2551.161 31 H 11 i 1/1/2014 0 0 H 11i 2/1/2014 0 0 H 11i 3/1/2014 0 0 H 11i 4/1/2014 0 0 H 11i 5/1/2014 0 0 H 11 i 6/1/2014 0 0 H 11i 7/1/2014 0 0 H 11i 8/1/2014 0 0 H 11i 9/1/2014 0 0 H 11 i 10/1/2014 0 0 H 11 i 11/1/2014 0 0 H 11i 12/1/2014 0 0 H12i 1/1/2014 973.3548 31 H12i 2/1/2014 988.7857 28 H12i 3/1/2014 1004.833 30 H12i 4/1/2014 1083.133 30 H12i 5/1/2014 987.9677 31 H12i 6/1/2014 975.8333 30 H12i 7/1/2014 952.5455 11 H12i 8/1/2014 0 0 Inj Vol Calc. (BBL, MCF) 13265.09 9945.996 7123.116 0 0 2682.29 15186.02 12946.6 10907.68 5703.158 4971.07 6304.943 7235.821 7997.844 6249.969 8221.355 12091.22 11284.88 12446.74 10106.66 11905.74 0 0 0 0 0 0 0 0 0 0 0 0 7743.289 6470.289 7257.727 13951.5 12971.67 11034.46 4056.093 0 Injection Rate Avg. (BWPD) 442.1698 320.8386 296.7965 0 0 447.0484 506.2007 431.5533 363.5892 183.9728 177.5382 203.3853 241.194 257.995 208.3323 274.0452 390.0392 376.1628 401.5077 348.5057 384.056 0 0 0 0 0 0 0 0 0 0 0 0 249.7835 231.0818 241.9242 465.0501 418.4411 367.8153 368.7357 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) H 12 i 9/1/2014 0 0 0 0 H 12 i 10/1/2014 0 0 0 0 H 12 i 11/1/2014 0 0 0 0 H 12i 12/1/2014 0 0 0 0 H15i 1/1/2014 760.4516 31 7584.555 244.6631 H15i 2/1/2014 1043.423 26 19063.53 733.2127 H15i 3/1/2014 1125 31 20504.81 661.4454 H15i 4/1/2014 1205.933 30 17613.5 587.1167 H15i 5/1/2014 1225.387 31 15690.99 506.1608 H15i 6/1/2014 1254.733 30 19532.42 651.0807 H15i 7/1/2014 1336.4 20 18495.24 924.7621 H15i 8/1/2014 737.4 10 2709.472 270.9472 H15i 9/1/2014 1147.857 21 12149.75 578.5594 H15i 10/1/2014 979 2 1507.671 753.8356 H15i 11/1/2014 1029.467 30 29738.27 991.2758 H15i 12/1/2014 1107.484 31 34799.4 1122.561 H17i 1/1/2014 1179.548 31 29873.31 963.6553 H17i 2/1/2014 1194.036 28 27650.74 987.5263 H17i 3/1/2014 1124.968 31 26864.84 866.6077 H17i 4/1/2014 1290.3 30 29872.49 995.7495 H17i 5/1/2014 1220.484 31 29588.06 954.4535 H17i 6/1/2014 1281.033 30 30129.12 1004.304 H17i 7/1/2014 1353.333 30 32951.61 1098.387 H17i 8/1/2014 1142.903 31 28886.97 931.8378 H17i 9/1/2014 1234.967 30 32407.12 1080.237 H17i 10/1/2014 1159.323 31 30267.7 976.3774 H17i 11/1/2014 1265.833 30 31670.94 1055.698 H17i 12/1/2014 1287.387 31 32560.24 1050.33 102LSi 1/1/2014 0 0 0 0 102LSi 2/1/2014 0 0 0 0 102LSi 3/1/2014 0 0 0 0 102LSi 4/1/2014 0 0 0 0 102LSi 5/1/2014 0 0 0 0 102LSi 6/1/2014 930.9615 26 7375.726 283.6818 1021 -Si 7/1/2014 883.28 25 6573.813 262.9525 1021 -Si 8/1/2014 0 0 0 0 1021 -Si 9/1/2014 0 0 0 0 1021 -Si 10/1/2014 0 0 0 0 1021 -Si 11/1/2014 788 1 259.1043 259.1043 1021 -Si 12/1/2014 753.8462 13 3070.105 236.1619 102SSi 1/1/2014 937.6429 28 10037.81 358.4932 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well 102SSi 102SSi 102SSi 102SSi 102SSi 102SSi 102SSi 102SSi 102SSi 102SSi 102SSi 108i 108i 108i 1081 108i 108i 108i 108i 108i 108i 108i 108i 109i 109i 109i 109i 109i 109i 109i 109i 109i 109i 109i 109i 1131 -Si 1131 -Si 1131 -Si 1131 -Si 1131 -Si 1131 -Si Month 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 WH Pressure Avg (psi) 950.8929 912.6552 929.8571 837.4839 860.7667 868.72 0 0 0 897 0 981.1613 1095.714 1101.452 1134.967 1150.032 1269.233 1270.133 1210.742 1278.967 1182.355 1259.967 1219.387 1452 1477.536 1347.742 1303.867 1344.129 1340.767 1284.367 1274.323 1485.233 1313.387 1373 1231.129 0 0 0 0 0 0 Days Operating 28 29 28 31 30 25 0 0 0 1 0 31 28 31 30 31 30 30 31 30 31 30 31 31 28 31 30 31 30 30 31 30 31 30 31 0 0 0 0 0 0 Inj Vol Calc. (BBL, MCF) 11071.24 11478.13 12055.97 13888.86 10162.81 8350.157 0 0 0 380.1852 0 48903.52 42610.93 43074.82 43202.94 44659.99 47520.41 47205.05 42091.14 43287.84 39858.94 46350 48238.94 53184.26 49537.85 41220.58 37374.05 44645.12 43060.62 38001.19 44626.16 54935.87 41216.61 45503.08 34065.3 0 0 0 0 0 0 Injection Rate Avg. (BWPD) 395.4015 395.7975 430.5703 448.0277 338.7604 334.0063 0 0 0 380.1852 0 1577.533 1521.819 1389.51 1440.098 1440.645 1584.014 1573.502 1357.779 1442.928 1285.772 1545 1556.095 1715.621 1769.209 1329.696 1245.802 1440.165 1435.354 1266.706 1439.554 1831.196 1329.568 1516.769 1098.881 0 0 0 0 0 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well 113 LSi 1131 -Si 113 LSi 1131 -Si 1131 -Si 113 LSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 113SSi 116i 116i 116i 116i 116i 116i 116i 116i 116i 116i 116i 116i 118i 118i 118i 118i 118i 118i 118i 118i 118i 118i 118i Month 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 WH Pressure Avg (psi) 1198.4 1019.333 0 0 0 1177 0 0 0 0 0 0 0 0 0 0 0 1163.125 984.7742 1020.929 987.8387 1049.533 1068.484 1023.267 1094.591 1074.952 1130.233 1051.323 1049.1 1059.226 1420.613 1427.214 1330.226 1305.567 1335.613 1480.167 1327.483 1300.194 1229.767 1360.774 1438.733 Days Operating 10 3 0 0 0 8 0 0 0 0 0 0 0 0 0 0 0 8 31 28 31 30 31 30 22 21 30 31 30 31 31 28 31 30 31 30 29 31 30 31 30 Inj Vol Calc. (BBL, MCF) 2317.508 470.0617 0 0 0 1436.636 0 0 0 0 0 0 0 0 0 0 0 1708.059 42915.78 39670.39 39464.64 41087.03 47897.97 42582.04 38604.35 28779.92 43512.01 42555.04 39966.87 45183.75 28863.13 28054.05 27177.93 35474.59 35863.85 40042.73 37508.1 44375.13 37687.81 42422.84 40183.04 Injection Rate Avg. (BWPD) 231.7508 156.6872 0 0 0 179.5794 0 0 0 0 0 0 0 0 0 0 0 213.5074 1384.38 1416.8 1273.053 1369.568 1545.096 1419.401 1754.743 1370.472 1450.4 1372.743 1332.229 1457.54 931.0687 1001.93 876.7075 1182.486 1156.898 1334.758 1293.383 1431.456 1256.26 1368.479 1339.435 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well 118i J02i J02i J02i J02i J02i J02i J02i J02i J02i J02i J02i J02i J15i J15i J15i J15i J15i J15i J15i J15i J15i J15i J15i J15i J17i J17i J17i J17i J17i J17i 117i J17i J17i J17i J17i J17i J 19Ai J 19Ai J 19Ai J 19Ai Month 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 WH Pressure Avg (psi) 1327.839 0 0 0 0 0 0 0 0 0 0 0 0 1033.548 974.5 700.4194 761.7667 814.3871 838.3 812.8 806.0645 811.6333 841.4194 834.4333 846.7742 1081.968 1095.393 1080.903 1095.167 1122.871 1028.433 1021.1 1276.733 1643.433 1061.452 1065.7 1083.484 870.4194 890.3214 897.3871 925.9333 Days Operating 31 0 0 0 0 0 0 0 0 0 0 0 0 31 24 31 30 31 30 30 31 30 31 30 31 31 28 31 30 31 30 30 30 30 31 30 31 31 28 31 30 Inj Vol Calc. (BBL, MCF) 45087.71 0 0 0 0 0 0 0 0 0 0 0 0 16717.4 14568.37 26791.25 31737.21 36296.2 35095.89 30334.57 27125.08 29369.3 34148.63 28411.75 30633.35 28474.05 24767.5 24444.3 28584.49 32639.53 23772.58 28281.19 27882.06 31419.21 34146.2 25657.9 28900.19 41261.57 36928.08 39453.73 39825.14 Injection Rate Avg. (BWPD) 1454.442 0 0 0 0 0 0 0 0 0 0 0 0 539.271 607.0154 864.2338 1057.907 1170.845 1169.863 1011.152 875.0026 978.9767 1101.569 947.0583 988.1727 918.5179 884.5537 788.5256 952.8165 1052.888 792.4194 942.7064 929.402 1047.307 1101.49 855.2634 932.2641 1331.018 1318.86 1272.701 1327.505 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Well J19Ai J19Ai J19Ai J19Ai J19Ai J 19Ai J19Ai J19Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai J20Ai S01131 -Si S01131Si S0161 -Si S0161 -Si S01131 -Si S0161 -.Si S01131 -Si S01131 -Si S01131 -Si S0161 -Si S01131 -Si S01131 -Si S0113SSi S0113SSi S0113SSi S016SSi S016SSi S016SSi S0113SSi S016SSi S016SSi Month 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 WH Pressure Avg (psi) 936.871 800.4615 674.3333 885.0333 1835 768.2 988.4 1055.097 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 710.0769 697.5517 0 0 0 0 0 0 0 0 0 Days Operating 31 26 30 30 10 10 30 31 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 26 29 0 0 0 0 0 0 0 0 0 Inj Vol Calc. (BBL, MCF) 43415.09 29478.26 34174.87 37979.09 8266.692 10199.79 34413.59 34599.08 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9410.818 34154.71 0 0 0 0 0 0 0 0 0 Injection Rate Avg. (BWPD) 1400.487 1133.779 1139.162 1265.97 826.6692 1019.979 1147.12 1116.099 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 361.9546 1177.749 0 0 0 0 0 0 0 0 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Inj Vol Calc. (BBL, MCF) 218.772 0 8707.43 0 12523.36 15241.04 14748.35 15824.97 15287.29 12059.85 0 0 0 6233.193 30122.62 60108.12 54593.81 64294.07 60789.61 66528.19 59063.37 55992.81 8875.075 0 3624.347 50829.54 56635.05 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Injection Rate Avg. (BWPD) 218.772 0 334.9011 0 500.9343 491.6465 508.5638 510.4828 509.5765 502.4936 0 0 0 296.8187 971.6976 1938.972 1949.779 2074.002 2026.32 2146.071 1968.779 1866.427 1775.015 0 1208.116 1694.318 1826.937 0 0 0 0 0 0 0 0 0 0 0 0 0 0 WH Pressure Well Month Avg (psi) Days Operating S0113SSi 10/1/2014 120 1 S0113SSi 11/1/2014 0 0 S0113SSi 12/1/2014 659.1154 26 S02i 1/1/2014 0 0 S02i 2/1/2014 946.32 25 S02i 3/1/2014 1033.871 31 S02i 4/1/2014 1023.69 29 S02i 5/1/2014 933.6129 31 S02i 6/1/2014 922.3333 30 S02i 7/1/2014 949.4167 24 S02i 8/1/2014 0 0 S02i 9/1/2014 0 0 S02i 10/1/2014 0 0 S02i 11/1/2014 1015.238 21 S02i 12/1/2014 1040.452 31 SO4i 1/1/2014 1086.387 31 SO4i 2/1/2014 1075.571 28 SO4i 3/1/2014 1113.226 31 SO4i 4/1/2014 1092.6 30 SO4i 5/1/2014 1097.613 31 SO4i 6/1/2014 1082.833 30 SO4i 7/1/2014 1094.967 30 SO4i 8/1/2014 1106 5 SO4i 9/1/2014 0 0 SO4i 10/1/2014 763.6667 3 SO4i 11/1/2014 1014.367 30 SO4i 12/1/2014 1103.935 31 S06i 1/1/2014 0 0 S06i 2/1/2014 0 0 S06i 3/1/2014 0 0 S06i 4/1/2014 0 0 S06i 5/1/2014 0 0 S06i 6/1/2014 0 0 S06i 7/1/2014 0 0 S06i 8/1/2014 0 0 S06i 9/1/2014 0 0 S06i 10/1/2014 0 0 S06i 11/1/2014 0 0 S06i 12/1/2014 0 0 S07LSi 1/1/2014 0 0 S071 -Si 2/1/2014 0 0 Inj Vol Calc. (BBL, MCF) 218.772 0 8707.43 0 12523.36 15241.04 14748.35 15824.97 15287.29 12059.85 0 0 0 6233.193 30122.62 60108.12 54593.81 64294.07 60789.61 66528.19 59063.37 55992.81 8875.075 0 3624.347 50829.54 56635.05 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Injection Rate Avg. (BWPD) 218.772 0 334.9011 0 500.9343 491.6465 508.5638 510.4828 509.5765 502.4936 0 0 0 296.8187 971.6976 1938.972 1949.779 2074.002 2026.32 2146.071 1968.779 1866.427 1775.015 0 1208.116 1694.318 1826.937 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) S071 -Si 3/1/2014 0 0 0 0 S07LSi 4/1/2014 0 0 0 0 S071 -Si 5/1/2014 0 0 0 0 S071 -Si 6/1/2014 0 0 0 0 S071 -Si 7/1/2014 0 0 0 0 S071 -Si 8/1/2014 0 0 0 0 S071 -Si 9/1/2014 0 0 0 0 S071 -Si 10/1/2014 0 0 0 0 S071 -Si 11/1/2014 0 0 0 0 S07LSi 12/1/2014 0 0 0 0 S07SSi 1/1/2014 0 0 0 0 S07SSi 2/1/2014 0 0 0 0 S07SSi 3/1/2014 0 0 0 0 S07SSi 4/1/2014 0 0 0 0 S07SSi 5/1/2014 0 0 0 0 S07SSi 6/1/2014 0 0 0 0 S07SSi 7/1/2014 0 0 0 0 S07SSi 8/1/2014 0 0 0 0 S07SSi 9/1/2014 0 0 0 0 S07SSi 10/1/2014 0 0 0 0 S07SSi 11/1/2014 0 0 0 0 S07SSi 12/1/2014 0 0 0 0 S091 -Si 1/1/2014 0 0 0 0 S091 -Si 2/1/2014 0 0 0 0 S091 -Si 3/1/2014 0 0 0 0 S091 -Si 4/1/2014 0 0 0 0 S091 -Si 5/1/2014 0 0 0 0 S091 -Si 6/1/2014 0 0 0 0 S091 -Si 7/1/2014 0 0 0 0 S091 -Si 8/1/2014 0 0 0 0 S091 -Si 9/1/2014 0 0 0 0 S09LSi 10/1/2014 0 0 0 0 S091 -Si 11/1/2014 0 0 0 0 S091 -Si 12/1/2014 0 0 0 0 S09SSi 1/1/2014 0 0 0 0 S09SSi 2/1/2014 0 0 0 0 S09SSi 3/1/2014 0 0 0 0 S09SSi 4/1/2014 0 0 0 0 S09SSi 5/1/2014 0 0 0 0 S09SSi 6/1/2014 0 0 0 0 S09SSi 7/1/2014 0 0 0 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) S09SSi 8/1/2014 0 0 0 0 S09SSi 9/1/2014 0 0 0 0 S09SSi 10/1/2014 0 0 0 0 S09SSi 11/1/2014 0 0 0 0 S09SSi 12/1/2014 0 0 0 0 S10ALSi 1/1/2014 0 0 0 0 S10ALSi 2/1/2014 0 0 0 0 S10ALSi 3/1/2014 0 0 0 0 S10ALSi 4/1/2014 0 0 0 0 S10ALSi 5/1/2014 0 0 0 0 S10ALSi 6/1/2014 0 0 0 0 S10ALSi 7/1/2014 0 0 0 0 S10ALSi 8/1/2014 0 0 0 0 S10ALSi 9/1/2014 0 0 0 0 S10ALSi 10/1/2014 0 0 0 0 S10ALSi 11/1/2014 0 0 0 0 S10ALSi 12/1/2014 0 0 0 0 S10ASSi 1/1/2014 0 0 0 0 S10ASSi 2/1/2014 0 0 0 0 S10ASSi 3/1/2014 0 0 0 0 S10ASSi 4/1/2014 0 0 0 0 S10ASSi 5/1/2014 0 0 0 0 S10ASSi 6/1/2014 0 0 0 0 S10ASSi 7/1/2014 0 0 0 0 S10ASSi 8/1/2014 0 0 0 0 S10ASSi 9/1/2014 372.2 5 1852.969 370.5939 S10ASSi 10/1/2014 0 0 0 0 S10ASSi 11/1/2014 0 0 0 0 S10ASSi 12/1/2014 0 0 0 0 S11i 1/1/2014 929 31 17791.04 573.9044 S11i 2/1/2014 842.5 28 13397.87 478.4954 S11i 3/1/2014 790.9355 31 14634.24 472.0722 S11i 4/1/2014 739.3667 30 13904.74 463.4914 S11i 5/1/2014 699.1613 31 13309.41 429.3358 S11i 6/1/2014 718.0714 28 12228.79 436.7425 S11i 7/1/2014 543.5 12 7812.998 651.0831 S11i 8/1/2014 0 0 0 0 S11i 9/1/2014 212 2 887.1598 443.5799 S11i 10/1/2014 0 0 0 0 S11i 11/1/2014 674.3333 3 814.7446 271.5815 S11i 12/1/2014 910.4815 27 9721.157 360.0428 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) S131 -Si 9/1/2014 0 0 0 0 S131 -Si 10/1/2014 306 1 286.558 286.558 S13LSi 11/1/2014 766.2917 24 6725.933 280.2472 S131 -Si 12/1/2014 908.8214 28 8641.511 308.6254 S13SSi 9/1/2014 0 0 0 0 S13SSi 10/1/2014 0 0 0 0 S13SSi 11/1/2014 0 0 0 0 S13SSi 12/1/2014 1087.087 23 6780.178 294.7903 S14i 1/1/2014 1025.129 31 21004.82 677.5748 S14i 2/1/2014 1022.036 28 16337.09 583.4674 S14i 3/1/2014 1023.29 31 17037.27 549.5894 S14i 4/1/2014 1039.1 30 18073.43 602.4477 S14i 5/1/2014 1034.226 31 16129.2 520.2968 S14i 6/1/2014 1030.3 30 16208.9 540.2967 S14i 7/1/2014 1042.677 31 17142.45 552.9822 S14i 8/1/2014 1047.419 31 15352.65 495.2466 S14i 9/1/2014 1077.667 6 2114.887 352.4812 S14i 10/1/2014 0 0 0 0 S14i 11/1/2014 0 0 0 0 S14i 12/1/2014 0 0 0 0 S15i 1/1/2014 1026.839 31 12164.31 392.3971 S15i 2/1/2014 1080.429 28 11759.11 419.9681 S15i 3/1/2014 1041.194 31 10161.58 327.7929 S15i 4/1/2014 1006.333 30 9562.011 318.7337 S15i 5/1/2014 1021.806 31 10722.12 345.8748 S15i 6/1/2014 1029.333 30 10723.03 357.4342 S15i 7/1/2014 1081.452 31 10674.09 344.3256 S15i 8/1/2014 1074 31 10243.72 330.4424 S15i 9/1/2014 1120.633 30 11917.11 397.2372 S15i 10/1/2014 1094.903 31 10889 351.2579 S15i 11/1/2014 1097.667 30 10392.33 346.411 S15i 12/1/2014 1063.6 30 10174.67 339.1558 S161 -Si 1/1/2014 908.7742 31 14087.49 454.4351 S16LSi 2/1/2014 976.5 28 16725.55 597.3409 S16LSi 3/1/2014 959.3871 31 16246.36 524.076 S16LSi 4/1/2014 953.8667 30 16375.29 545.8428 S16LSi 5/1/2014 953.6129 31 17139.36 552.8825 S16LSi 6/1/2014 950.7333 30 16358.73 545.2911 S161 -Si 7/1/2014 959.2258 31 17555.1 566.2934 S161 -Si 8/1/2014 930.2258 31 16790.69 541.6353 S161 -Si 9/1/2014 871.7273 11 5051.517 459.2288 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) S 16 LS i 10/1/2014 0 0 0 0 S16LSi 11/1/2014 0 0 0 0 S161 -Si 12/1/2014 740.625 8 2218.709 277.3387 S16SSi 1/1/2014 1054.645 31 17529.32 565.462 S16SSi 2/1/2014 1084.464 28 15574.63 556.2367 S16SSi 3/1/2014 1105.032 31 15457.16 498.6179 S16SSi 4/1/2014 1176.2 30 15387.22 512.9074 S16SSi 5/1/2014 1160.968 31 16025.51 516.9521 S16SSi 6/1/2014 1104.313 16 6554.792 409.6745 S16SSi 7/1/2014 0 0 0 0 S16SSi 8/1/2014 0 0 0 0 S16SSi 9/1/2014 0 0 0 0 S16SSi 10/1/2014 0 0 0 0 S16SSi 11/1/2014 690.3333 3 988.1927 329.3976 S16SSi 12/1/2014 870.9677 31 14172.02 457.1619 S18LSi 1/1/2014 829.0645 31 16588.19 535.103 S18LSi 2/1/2014 762.1786 28 11533.96 411.9272 S18LSi 3/1/2014 803.3548 31 13834.94 446.2883 S181 -Si 4/1/2014 842.4333 30 14726.11 490.8705 S181 -Si 5/1/2014 836.5484 31 13062.93 421.3849 S18LSi 6/1/2014 810.6 30 13854.25 461.8085 S18LSi 7/1/2014 872.5806 31 16526.46 533.1116 S18LSi 8/1/2014 852.9032 31 15278.1 492.8419 S181 -Si 9/1/2014 792.0667 30 14779.17 492.6391 S181 -Si 10/1/2014 720 4 1608.302 402.0755 S181 -Si 11/1/2014 0 0 0 0 S181 -Si 12/1/2014 692.8261 23 7035.174 305.8771 S18SSi 1/1/2014 835.9677 31 13484.63 434.9879 S18SSi 2/1/2014 764.4286 28 9512.91 339.7468 S18SSi 3/1/2014 827.1613 31 13886.75 447.9597 S18SSi 4/1/2014 873.2667 30 15207.77 506.9257 S18SSi 5/1/2014 870.4516 31 15368.63 495.7622 S18SSi 6/1/2014 857.1333 30 14150.59 471.6865 S18SSi 7/1/2014 913.2903 31 16398.49 528.9835 S18SSi 8/1/2014 875.5161 31 14662.73 472.9912 S18SSi 9/1/2014 855 8 3704.604 463.0755 S18SSi 10/1/2014 0 0 0 0 S18SSi 11/1/2014 0 0 0 0 S18SSi 12/1/2014 850.8947 19 5089.572 267.8722 S20LSi 1/1/2014 0 0 0 0 S201 -Si 2/1/2014 0 0 0 0 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool WH Pressure Inj Vol Calc. (BBL, Injection Rate Avg. Well Month Avg (psi) Days Operating MCF) (BWPD) S201 -Si 3/1/2014 0 0 0 0 S201 -Si 4/1/2014 0 0 0 0 S201 -Si 5/1/2014 505.3 10 3562.794 356.2794 S201 -Si 6/1/2014 492.0714 28 9962.196 355.7927 S201 -Si 7/1/2014 467.6774 31 9506.202 306.6517 S201 -Si 8/1/2014 448.8065 31 10708.29 345.4287 S201 -Si 9/1/2014 443.6071 28 8804.933 314.4619 S201 -Si 10/1/2014 358 4 911.2841 227.821 S201 -Si 11/1/2014 523 3 625.7476 208.5825 S201 -Si 12/1/2014 581.6774 31 8657.14 279.2626 S20SSi 1/1/2014 0 0 0 0 S20SSi 2/1/2014 0 0 0 0 S20SSi 3/1/2014 0 0 0 0 S20SSi 4/1/2014 0 0 0 0 S20SSi 5/1/2014 0 0 0 0 S20SSi 6/1/2014 423.1111 27 11572.52 428.6117 S20SSi 7/1/2014 0 0 0 0 S20SSi 8/1/2014 0 0 0 0 S20SSi 9/1/2014 0 0 0 0 S20SSi 10/1/2014 0 0 0 0 S20SSi 11/1/2014 0 0 0 0 S20SSi 12/1/2014 600.5 28 8778.031 313.5011 S26LSi 1/1/2014 872.0968 31 16469.11 531.2615 S261 -Si 2/1/2014 994.3333 6 3036.843 506.1404 S261 -Si 3/1/2014 0 0 0 0 S261 -Si 4/1/2014 0 0 0 0 S261 -Si 5/1/2014 0 0 0 0 S261 -Si 6/1/2014 855.3333 27 7447.074 275.8176 S261 -Si 7/1/2014 999.7097 31 14603.03 471.0654 S261 -Si 8/1/2014 992.7419 31 13460.12 434.1975 S261 -Si 9/1/2014 1025.7 30 13974.03 465.8011 S26LSi 10/1/2014 1021 4 1728.66 432.1649 S261 -Si 11/1/2014 867.6923 26 6607.344 254.1286 S261 -Si 12/1/2014 903 31 7957.165 256.6827 S26SSi 41640 638.6452 31 10191.3 328.7516 S26SSi 41671 576.8333 6 1999.385 333.2309 S26SSi 41699 0 0 0 0 S26SSi 41730 0 0 0 0 S26SSi 41760 0 0 0 0 S26SSi 41791 770 5 1780.208 356.0415 S26SSi 41821 827.7097 31 10199.48 329.0154 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Inj Vol Calc. (BBL, MCF) 8915.537 9735.541 1333.399 6909.166 8801.606 9614.013 1046.401 4195.579 7974.476 9073.761 7160.814 9724.3 8824.548 9706.8 5132.582 1360.856 6940.362 0 0 7889.59 10386.37 9448.202 8651.351 10040.78 10764.31 10312.16 8216.535 3235.83 7948.686 15333.75 0 13386.9 18029.14 14388.69 13667.2 11777.43 15116.74 11833.34 13277.68 9969.602 16425.01 Injection Rate Avg. (BWPD) 297.1846 324.518 333.3497 276.3666 283.9228 310.1295 209.2802 199.7895 265.8159 302.4587 246.9246 313.6871 304.2947 323.56 244.4087 272.1711 231.3454 0 0 292.207 346.2122 304.7807 288.3784 323.8962 347.2359 343.7386 304.3161 231.1307 264.9562 696.9887 0 608.4952 600.9714 464.1513 455.5733 379.9171 487.6369 394.4446 442.5895 474.7429 529.8389 WH Pressure Well Month Avg (psi) Days Operating S26SSi 41852 804.3333 30 S26SSi 41883 836.0667 30 S26SSi 41913 852.5 4 S26SSi 41944 805.68 25 S26SSi 41974 836.8387 31 S301 -Si 41640 871.9355 31 S30LSi 41671 726.6 5 S301 -Si 41699 715.0952 21 S301 -Si 41730 817.7 30 S301 -Si 41760 866.8667 30 S301 -Si 41791 830.1034 29 S301 -Si 41821 897.871 31 S30LSi 41852 903.8276 29 S301 -Si 41883 923.7667 30 S301 -Si 41913 833.9048 21 S301 -Si 41944 824.8 5 S301 -Si 41974 838.9333 30 S30SSi 41640 0 0 S30SSi 41671 0 0 S30SSi 41699 821.8889 27 S30SSi 41730 837.5 30 S30SSi 41760 859.3226 31 S30SSi 41791 833.7667 30 S30SSi 41821 882.9032 31 S30SSi 41852 922.5806 31 S30SSi 41883 906.2667 30 S30SSi 41913 831.5185 27 S30SSi 41944 723.8571 14 S30SSi 41974 806.9333 30 S31i 41640 1242.773 22 S31i 41671 0 0 S31i 41699 1054.273 22 S31i 41730 1133.233 30 S31i 41760 1100.903 31 S31i 41791 1094.367 30 S31i 41821 1062.742 31 S31i 41852 1108.097 31 S31i 41883 1084.9 30 S31i 41913 1074.067 30 S31i 41944 1023.333 21 S31i 41974 1103.161 31 Inj Vol Calc. (BBL, MCF) 8915.537 9735.541 1333.399 6909.166 8801.606 9614.013 1046.401 4195.579 7974.476 9073.761 7160.814 9724.3 8824.548 9706.8 5132.582 1360.856 6940.362 0 0 7889.59 10386.37 9448.202 8651.351 10040.78 10764.31 10312.16 8216.535 3235.83 7948.686 15333.75 0 13386.9 18029.14 14388.69 13667.2 11777.43 15116.74 11833.34 13277.68 9969.602 16425.01 Injection Rate Avg. (BWPD) 297.1846 324.518 333.3497 276.3666 283.9228 310.1295 209.2802 199.7895 265.8159 302.4587 246.9246 313.6871 304.2947 323.56 244.4087 272.1711 231.3454 0 0 292.207 346.2122 304.7807 288.3784 323.8962 347.2359 343.7386 304.3161 231.1307 264.9562 696.9887 0 608.4952 600.9714 464.1513 455.5733 379.9171 487.6369 394.4446 442.5895 474.7429 529.8389 Exhibit 3-F Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Inj Vol Calc. (BBL, MCF) 9284.041 2191.112 9975.696 10288.69 10373.65 9355.073 10098.49 11414.38 5999.26 0 0 6447.619 0 0 0 0 0 0 0 0 0 0 1101.531 979.7317 Injection Rate Avg. (BWPD) 488.6337 273.889 321.7966 342.9563 334.6339 311.8358 336.6162 368.2057 399.9506 0 0 257.9047 0 0 0 0 0 0 0 0 0 0 220.3062 244.9329 WH Pressure Well Month Avg (psi) Days Operating S33ALSi 41640 1046.789 19 S33ALSi 41671 603.75 8 S33ALSi 41699 782.0968 31 S33ALSi 41730 769.7667 30 S33ALSi 41760 811.2258 31 S33ALSi 41791 796.4667 30 S33ALSi 41821 861.9 30 S33ALSi 41852 840.9355 31 S33ALSi 41883 690.2 15 S33ALSi 41913 0 0 S33ALSi 41944 0 0 S33ALSi 41974 1014.84 25 S33ASSi 41640 0 0 S33ASSi 41671 0 0 S33ASSi 41699 0 0 S33ASSi 41730 0 0 S33ASSi 41760 0 0 S33ASSi 41791 0 0 S33ASSi 41821 0 0 S33ASSi 41852 0 0 S33ASSi 41883 0 0 S33ASSi 41913 0 0 S33ASSi 41944 216 5 S33ASSi 41974 38.5 4 Inj Vol Calc. (BBL, MCF) 9284.041 2191.112 9975.696 10288.69 10373.65 9355.073 10098.49 11414.38 5999.26 0 0 6447.619 0 0 0 0 0 0 0 0 0 0 1101.531 979.7317 Injection Rate Avg. (BWPD) 488.6337 273.889 321.7966 342.9563 334.6339 311.8358 336.6162 368.2057 399.9506 0 0 257.9047 0 0 0 0 0 0 0 0 0 0 220.3062 244.9329 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Milne Point Unit Allocation Factor Report 1/1/2014 - 12/31/2014 Date Oil Water 1/1/2014 0.90 1.29 1/2/2014 0.89 1.16 1/3/2014 0.89 1.20 1/4/2014 0.89 1.15 1/5/2014 0.90 1.18 1/6/2014 0.90 1.22 1/7/2014 0.90 1.20 1/8/2014 0.90 1.19 1/9/2014 0.90 1.18 1/10/2014 0.89 1.16 1/11/2014 0.92 1.16 1/12/2014 0.90 1.16 1/13/2014 0.88 1.14 1/14/2014 0.90 1.18 1/15/2014 0.89 1.26 1/16/2014 0.89 1.20 1/17/2014 0.88 1.20 1/18/2014 0.89 1.24 1/19/2014 0.89 1.26 1/20/2014 0.86 1.18 1/21/2014 0.89 1.22 1/22/2014 0.87 1.23 1/23/2014 0.88 1.18 1/24/2014 0.88 1.20 1/25/2014 0.86 1.15 1/26/2014 0.84 1.12 1/27/2014 0.88 1.13 1/28/2014 0.88 1.18 1/29/2014 0.87 1.17 1/30/2014 0.87 1.15 1/31/2014 0.89 1.04 2/1/2014 0.88 1.12 2/2/2014 0.89 1.14 2/3/2014 0.88 1.09 2/4/2014 0.89 1.18 2/5/2014 0.89 1.22 2/6/2014 0.87 1.24 2/7/2014 0.88 1.18 2/8/2014 0.85 1.24 2/9/2014 0.86 1.21 2/10/2014 0.85 1.25 Gas 0.85 0.82 0.83 0.82 0.81 0.81 0.81 0.82 0.82 0.81 0.83 0.82 0.82 0.82 0.83 0.83 0.83 0.80 0.80 0.79 0.81 0.80 0.81 0.82 0.81 0.81 0.82 0.88 1.01 1.01 0.99 1.01 1.01 1.02 1.04 1.05 1.05 1.05 1.06 1.03 1.02 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 2/11/2014 2/12/2014 2/13/2014 2/14/2014 2/15/2014 2/16/2014 2/17/2014 2/18/2014 2/19/2014 2/20/2014 2/21/2014 2/22/2014 2/23/2014 2/24/2014 2/25/2014 2/26/2014 2/27/2014 2/28/2014 3/1/2014 3/2/2014 3/3/2014 3/4/2014 3/5/2014 3/6/2014 3/7/2014 3/8/2014 3/9/2014 3/10/2014 3/11/2014 3/12/2014 3/13/2014 3/14/2014 3/15/2014 3/16/2014 3/17/2014 3/18/2014 3/19/2014 3/20/2014 3/21/2014 3/22/2014 3/23/2014 3/24/2014 3/25/2014 Oil Water 0.87 1.20 0.86 1.28 0.86 1.23 0.88 1.17 0.87 1.20 0.87 1.16 0.85 1.19 0.85 1.20 0.84 1.21 0.87 1.19 0.87 1.22 0.87 1.25 0.89 1.21 0.87 1.23 0.87 1.24 0.88 1.21 0.86 1.23 0.88 1.14 0.85 1.08 0.84 1.02 0.84 1.06 0.85 1.02 0.84 1.02 0.83 1.13 0.85 1.15 0.88 1.19 0.81 1.09 0.85 1.18 0.85 1.13 0.88 1.09 0.89 1.09 0.87 1.07 0.88 1.09 0.90 1.10 0.85 1.07 0.86 1.04 0.85 1.03 0.86 1.07 0.84 1.05 0.84 1.06 0.83 1.03 0.83 1.06 0.83 1.07 Gas 1.02 1.06 1.05 1.04 1.03 1.03 1.02 1.03 1.03 1.05 1.06 1.03 1.04 1.07 1.04 1.06 1.05 1.05 1.00 1.01 1.01 0.99 0.97 0.98 0.99 0.95 0.91 0.94 1.01 1.02 1.01 1.00 1.01 0.97 0.94 0.92 0.87 0.86 0.82 0.83 0.82 0.87 0.86 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 3/26/2014 3/27/2014 3/28/2014 3/29/2014 3/30/2014 3/31/2014 4/1/2014 4/2/2014 4/3/2014 4/4/2014 4/5/2014 4/6/2014 4/7/2014 4/8/2014 4/9/2014 4/10/2014 4/11/2014 4/12/2014 4/13/2014 4/14/2014 4/15/2014 4/16/2014 4/17/2014 4/18/2014 4/19/2014 4/20/2014 4/21/2014 4/22/2014 4/23/2014 4/24/2014 4/25/2014 4/26/2014 4/27/2014 4/28/2014 4/29/2014 4/30/2014 5/1/2014 5/2/2014 5/3/2014 5/4/2014 5/5/2014 5/6/2014 5/7/2014 Oil Water 0.85 1.13 0.87 1.09 0.86 1.09 0.88 1.06 0.87 1.05 0.87 1.05 0.86 1.10 0.87 1.07 0.85 1.07 0.84 1.06 0.84 1.03 0.84 1.03 0.83 1.03 0.84 1.03 0.84 1.05 0.84 1.02 0.84 1.03 0.85 1.03 0.84 1.04 0.82 1.05 0.83 1.09 0.84 1.04 0.86 1.02 0.85 1.09 0.85 0.99 0.85 1.04 0.84 1.07 0.84 1.02 0.84 1.10 0.80 1.27 0.81 1.32 0.84 1.09 0.77 1.10 0.75 1.32 0.71 1.33 0.81 1.31 0.82 1.30 0.88 1.32 0.84 1.34 0.83 1.34 0.82 1.17 0.83 1.11 0.85 1.16 Gas 0.90 0.88 0.92 0.94 0.87 0.87 0.88 0.89 0.88 0.90 0.87 0.88 0.86 0.86 0.86 0.81 0.80 0.83 0.80 0.82 0.94 0.80 0.80 0.77 0.77 0.79 0.82 0.80 0.85 0.76 0.73 0.74 0.72 0.74 0.75 0.76 0.76 0.87 1.07 0.81 0.70 0.70 0.79 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 5/8/2014 5/9/2014 5/10/2014 5/11/2014 5/12/2014 5/13/2014 5/14/2014 5/15/2014 5/16/2014 5/17/2014 5/18/2014 5/19/2014 5/20/2014 5/21/2014 5/22/2014 5/23/2014 5/24/2014 5/25/2014 5/26/2014 5/27/2014 5/28/2014 5/29/2014 5/30/2014 5/31/2014 6/1/2014 6/2/2014 6/3/2014 6/4/2014 6/5/2014 6/6/2014 6/7/2014 6/8/2014 6/9/2014 6/10/2014 6/11/2014 6/12/2014 6/13/2014 6/14/2014 6/15/2014 6/16/2014 6/17/2014 6/18/2014 6/19/2014 Oil Water 0.81 1.14 0.88 1.19 0.89 1.18 0.88 1.21 0.88 1.25 0.88 1.29 0.87 1.24 0.89 1.24 0.90 1.23 0.89 1.22 0.90 1.24 0.89 1.19 0.89 1.13 0.87 1.14 0.86 1.05 0.87 1.06 0.86 1.05 0.87 1.05 0.85 1.06 0.89 1.08 0.89 1.05 0.89 1.10 0.87 1.09 0.88 1.09 0.88 1.12 0.90 1.07 0.89 1.12 0.88 1.10 0.89 1.08 0.89 1.10 0.87 1.10 0.85 1.05 0.87 1.03 0.86 1.07 0.88 1.07 0.86 1.06 0.84 1.06 0.82 1.08 0.88 1.05 0.84 1.08 0.86 1.08 0.83 1.05 0.86 1.08 Gas 0.80 0.82 1.08 0.82 0.76 0.75 0.79 0.80 0.75 0.94 0.94 0.78 0.82 0.81 0.82 0.80 0.80 0.79 0.78 0.82 0.80 0.78 0.86 0.90 0.93 0.98 0.97 0.89 0.98 0.94 0.87 0.90 0.92 0.89 0.90 0.93 0.90 0.87 0.85 0.88 0.89 0.88 0.86 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 6/20/2014 6/21/2014 6/22/2014 6/23/2014 6/24/2014 6/25/2014 6/26/2014 6/27/2014 6/28/2014 6/29/2014 6/30/2014 7/1/2014 7/2/2014 7/3/2014 7/4/2014 7/5/2014 7/6/2014 7/7/2014 7/8/2014 7/9/2014 7/10/2014 7/11/2014 7/12/2014 7/13/2014 7/14/2014 7/15/2014 7/16/2014 7/17/2014 7/18/2014 7/19/2014 7/20/2014 7/21/2014 7/22/2014 7/23/2014 7/24/2014 7/25/2014 7/26/2014 7/27/2014 7/28/2014 7/29/2014 7/30/2014 7/31/2014 8/1/2014 Oil Water 0.80 1.28 0.86 1.20 0.88 1.12 0.89 1.09 0.90 1.12 0.87 1.10 0.89 1.05 0.90 1.05 0.87 0.99 0.89 1.07 0.89 1.06 0.89 1.07 0.87 1.07 0.89 1.03 0.91 1.03 0.91 1.04 0.92 1.04 0.93 1.04 0.92 1.06 0.92 1.02 0.93 1.03 0.92 1.03 0.91 1.02 0.89 1.02 0.93 1.02 0.94 0.89 0.92 0.95 0.91 1.02 0.90 1.03 0.89 1.02 0.96 1.02 0.91 1.06 0.93 1.06 0.91 1.02 0.86 1.11 0.88 0.99 0.92 1.20 0.91 1.15 0.93 1.16 0.95 1.19 0.95 1.12 0.93 1.08 0.94 1.11 Gas 0.91 0.91 0.84 0.92 0.87 0.92 0.91 0.92 0.95 0.98 1.00 0.96 0.94 0.97 0.99 0.93 0.98 1.00 1.04 0.83 1.03 1.00 1.02 1.02 1.06 1.04 1.06 1.02 1.03 1.05 1.06 1.01 1.04 1.01 0.90 0.91 1.01 0.96 1.01 1.07 1.06 0.99 1.04 Exhibit 3-G 2014 Facility Allocation Factors Date Oil Water Gas 8/2/2014 0.94 1.11 1.05 8/3/2014 0.92 1.10 1.02 8/4/2014 0.97 1.10 1.05 8/5/2014 0.95 1.19 1.02 8/6/2014 0.89 1.24 1.02 8/7/2014 0.92 1.24 1.03 8/8/2014 0.92 1.22 0.97 8/9/2014 0.89 1.26 0.97 8/10/2014 0.91 1.26 0.98 8/11/2014 0.89 1.26 0.98 8/12/2014 0.91 1.25 0.98 8/13/2014 0.90 1.29 1.02 8/14/2014 0.91 1.23 1.04 8/15/2014 0.90 1.22 1.04 8/16/2014 0.88 1.28 1.02 8/17/2014 0.91 1.21 1.03 8/18/2014 0.95 1.27 1.02 8/19/2014 0.91 1.22 0.92 8/20/2014 0.88 1.26 0.85 8/21/2014 0.91 1.25 0.93 8/22/2014 0.87 1.20 0.89 8/23/2014 0.87 1.28 0.87 8/24/2014 0.88 1.25 0.88 8/25/2014 0.86 1.31 0.84 8/26/2014 0.89 1.27 0.91 8/27/2014 0.88 1.22 0.92 8/28/2014 0.88 1.19 0.88 8/29/2014 0.87 1.16 0.76 8/30/2014 0.88 1.07 0.78 8/31/2014 0.87 1.30 0.83 9/1/2014 0.88 1.25 0.84 9/2/2014 0.86 1.19 0.93 9/3/2014 0.91 1.18 0.94 9/4/2014 0.88 1.23 0.92 9/5/2014 0.92 1.26 0.96 9/6/2014 0.92 1.23 0.96 9/7/2014 0.92 1.06 0.94 9/8/2014 0.92 0.96 0.94 9/9/2014 0.91 0.97 0.92 9/10/2014 0.90 1.25 0.95 9/11/2014 0.91 1.25 0.98 9/12/2014 0.89 1.22 0.96 9/13/2014 0.87 1.19 0.94 Milne Point Unit Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 9/14/2014 9/15/2014 9/16/2014 9/17/2014 9/18/2014 9/19/2014 9/20/2014 9/21/2014 9/22/2014 9/23/2014 9/24/2014 9/25/2014 9/26/2014 9/27/2014 9/28/2014 9/29/2014 9/30/2014 10/1/2014 10/2/2014 10/3/2014 10/4/2014 10/5/2014 10/6/2014 10/7/2014 10/8/2014 10/9/2014 10/10/2014 10/11/2014 10/12/2014 10/13/2014 10/14/2014 10/15/2014 10/16/2014 10/17/2014 10/18/2014 10/19/2014 10/20/2014 10/21/2014 10/22/2014 10/23/2014 10/24/2014 10/25/2014 10/26/2014 Oil Water 0.86 1.19 0.88 1.21 0.90 1.20 0.90 1.20 0.90 1.22 0.91 1.17 0.88 1.16 0.88 1.08 0.90 1.07 0.90 1.06 0.89 1.04 0.91 1.03 0.88 1.08 0.89 1.06 0.86 1.06 0.92 1.03 0.88 1.05 0.85 1.02 0.85 1.03 0.85 1.02 0.86 1.06 0.87 1.04 0.87 1.06 0.86 1.00 0.85 1.06 0.85 1.07 0.84 1.08 0.83 1.05 0.82 1.06 0.84 1.03 0.82 1.08 0.84 1.07 0.86 1.00 0.85 1.00 0.85 1.04 0.87 1.03 0.73 1.45 0.78 1.19 0.85 1.23 0.87 1.25 0.87 1.23 0.87 1.19 0.88 1.01 Gas 0.93 0.97 0.97 0.97 0.99 1.02 1.02 1.00 1.00 1.04 0.99 1.00 0.98 0.99 0.99 1.00 1.00 0.95 0.98 1.02 1.02 1.02 0.98 0.89 0.91 0.96 0.94 0.89 0.96 0.99 0.99 0.99 0.99 0.99 0.96 0.93 0.88 0.83 0.84 0.86 0.85 0.79 0.83 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 10/27/2014 10/28/2014 10/29/2014 10/30/2014 10/31/2014 11/1/2014 11/2/2014 11/3/2014 11/4/2014 11/5/2014 11/6/2014 11/7/2014 11/8/2014 11/9/2014 11/10/2014 11/11/2014 11/12/2014 11/13/2014 11/14/2014 11/15/2014 11/16/2014 11/17/2014 11/18/2014 11/19/2014 11/20/2014 11/21/2014 11/22/2014 11/23/2014 11/24/2014 11/25/2014 11/26/2014 11/27/2014 11/28/2014 11/29/2014 11/30/2014 12/1/2014 12/2/2014 12/3/2014 12/4/2014 12/5/2014 12/6/2014 12/7/2014 12/8/2014 Oil Water 0.86 0.97 0.85 0.99 0.84 0.94 0.85 0.98 0.85 0.96 0.86 0.98 0.91 1.06 0.87 0.94 0.86 1.04 0.85 0.75 0.85 0.69 0.84 0.79 0.86 1.05 0.86 1.02 0.85 1.07 0.85 1.29 0.86 1.23 0.85 1.21 0.85 1.21 0.88 1.17 0.88 1.10 0.85 1.08 0.85 1.11 0.85 1.11 0.86 1.14 0.87 1.13 0.87 1.10 0.86 1.10 0.86 1.09 0.84 1.09 0.84 1.11 0.86 1.11 0.86 1.10 0.85 1.09 0.84 1.11 0.86 1.11 0.86 1.14 0.87 1.07 0.87 1.03 0.84 1.10 0.87 1.11 0.88 1.08 0.86 1.06 Gas 0.82 0.82 0.81 0.85 0.85 0.90 0.98 0.89 0.88 0.83 0.86 0.81 0.72 0.77 0.72 0.72 0.72 0.70 0.77 0.92 0.94 0.82 0.86 0.86 0.85 0.85 0.86 0.85 0.86 0.87 0.85 0.83 0.84 0.85 0.84 0.85 0.87 0.86 0.87 0.87 0.90 0.91 0.90 Exhibit 3-G 2014 Facility Allocation Factors Milne Point Unit Date 12/9/2014 12/10/2014 12/11/2014 12/12/2014 12/13/2014 12/14/2014 12/15/2014 12/16/2014 12/17/2014 12/18/2014 12/19/2014 12/20/2014 12/21/2014 12/22/2014 12/23/2014 12/24/2014 12/25/2014 12/26/2014 12/27/2014 12/28/2014 12/29/2014 12/30/2014 12/31/2014 Oil Water 0.88 1.10 0.89 1.12 0.86 1.15 0.86 1.12 0.86 1.10 0.88 1.15 0.85 1.12 0.85 1.07 0.85 1.06 0.83 1.06 0.87 1.04 0.86 1.06 0.87 1.03 0.89 1.13 0.88 1.13 0.88 1.15 0.87 1.14 0.88 1.06 0.87 1.04 0.88 1.04 0.87 1.09 0.87 1.02 0.88 1.08 Gas 0.92 0.91 0.90 0.89 0.88 0.91 0.88 0.92 0.88 0.88 0.85 0.87 0.84 0.88 0.88 0.86 0.85 0.84 0.85 0.87 0.86 0.85 0.87 Mean 0.87 1.12 0.91 Standard Deviation 0.032 0.095 0.091 Section 4 Sag River Oil Pool List of Exhibits Total Reservoir Production Plot 4-A Total Reservoir Injection Plot 4-B Pertinent Data Summary 4-C Reservoir Voidage Balance 4-D Static Pressure Data 4-E Injection Rate & Pressure Data By Well 4-F Sag River Oil Pool Waterflood Project Summary A Participating Area for the Sag was approved in 2005. On December 31, 2008, the PA contracted to a 160 acre area around the active wells, MPF -33A and MPF -73A. During 2014, there were two active Sag production wells (MPK-33 and MPC -23) and no active injection wells. Exhibit 4-A shows a production plot for the Sag River reservoir covering the entire history through December 2014. There was no production from the reservoir in most of 1999 and the entire year of 2000 because it was not economical to repair the failed ESPs. At the end of 2000, one well (MPC -23) was converted to a jet pump completion. In 2001, one well (MPF -33A) was side-tracked and completed with a jet pump completion and another well (MPF -73A) was deepened from an idle Kuparuk well into the Sag River reservoir as an injector. One producing well (MPC -23) was shut in for integrity reasons in 2002 and the injection well (MPF -73A) was changed to water service only in 2006 due to tubing to inner annulus communication on gas injection. MPK-33 was swapped back to Kuparuk production starting 9/10/14. MPC -23 is the only producer on producing from the Sag as of December 31, 2014. The Sag River Pool oil production averaged 410 STBD, gas production averaged 495 MSCFD (average GOR of 1207 SCF/BBL), and water production averaged 179 STBD in 2014. Cumulative production through the end of 2014 is 2.59 MMSTB of oil, 2.71 BSCF of gas, and 2.47 MMSTB of water. In 2014, the average water cut was 30.4%, a significant increase over the 2013 average water cut of 0%. The increase in water cut was a result of a sharp increase in watercut in MPK-33 which eventually led to decision to convert back to Kuparuk production in September 2014. In 2014, the average GOR was 1207 SCF/STB, an increase over the 2013 average GOR of 636 SCF/STB. Exhibit 4-13 shows an injection plot for the Sag River reservoir through December 2014. The only injector (MPF -73A) started water injection in July 2002. The water injection rate for 2012 averaged 790 BWD, with no gas injected. However, in 2013 and 2014, there was no water or gas injection into MPF -73A as the offset producer, MPF -33A, was offline. Cumulative water injection since waterflood startup through the end of 2014 remained the same as at the end of 2012 at 3.02 MMSTB and cumulative gas injection at the end of 2014 is 0.32 BSCF. Exhibit 4-C presents a summary of the pertinent production information for the Sag River Oil Pool. Exhibit 4-D shows a monthly breakdown of production and injection data for the report period. Exhibit 4-E presents the reservoir pressure data for the Sag River wells taken during 2014. Three pressure surveys were obtained. MPF -33A has been shut-in since 4/9/12 due to a stuck jet pump in the tubing string. During 2012 and 2014, options were pursued to remove the pump, all of which were unsuccessful. The stuck jet pump is preventing access to the reservoir to obtain a SBHP survey. Exhibit 4-F provides a monthly summary of the injection rate and injection pressure data for the Sag River Oil Pool injector. It shows no injection into the Sag reservoir during 2014. Exhibit 4-A Hilcorp Alaska - Milne Point Unit SAG Reservoir, Total Production 1000000 100000 + Water Cut %, SAG t Producers Online —>t—Gas/Oil Ratio SAG 10000 y LL U 1000 ? a 0 IL 100 10 e lid + Water Cut %, SAG t Producers Online —>t—Gas/Oil Ratio SAG 10000 y LL U 1000 ? a 0 IL 100 10 1000000 100000 a m 10000 C c 1000 V d C d 100 10 Exhibit 4-B Hilcorp Alaska - Milne Point Unit SAG Reservoir, Total Injection 10000000 1000000 >a 0 � LL 0 N 100000 LL y N r2 � C c.2 10000 v d a c 1000 100 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 Water Inj Cum SAG — Water Inj Rate SAG Gas Inj Rate SAG Solvent Inj Cum SAG 1 1 0 Gas Inj Cum SAG t Solvent Inj Rate SAG 0 1 I I 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 � Water Injectors OnLine u Gas Injectors OnLine • MI Injectors OnLine — c � p N Exhibit 4-C Milne Point Unit - Sag River Oil Pool SUMMARY OF PERTINENT DATA As of December 31, 2014 WATERFLOOD START-UP DATE: July 1, 2002 PRODUCTION Prior to Waterflood Start -Up: Oil (MSTB) 1,299 Gas (MMSCF) 1,302 Water (MSTB) 1,481 Since Waterflood Start -Up: Oil (MSTB) 1,403 Gas (MMSCF) 1,478 Water (MSTB) 986 FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB) 3,020 Injection Gas (MMSCF) 0 Lean Gas (MMSCF) 0 Solvent (MMSCF) 0 AVERAGE OF PRESSURES OBTAINED IN 2014 (a) 7,000' TVD ss December, 2014 Pressure (psig) 4,414 WELL COUNT (Wells in Operation)* Production Wells 2 WAG Injection 0 Water Only Injection 0 Gas Only Injection 0 Notes: Reflects ONLY operable wells. Exhibit 4-D RESERVOIR VOIDAGE BALANCE Milne Point Unit Sag River Oil Pool January - December 2014 Production: Injection: Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage Month Prod Rate Prod Rate Prod Rale Voidage Inj Rate Inj Rate Replacement Replacement Balance (stb/day) (stb/day) (mscf/day) (rbbl/day) (stb/day) (mscf/day) (rbbl/day) Ratio (rbbl/day) 1/31/2014 696 0 650 1,115 0 0 0 0.00 -1,115 2/28/2014 663 0 774 1,156 0 0 0 0.00 -1,156 3/31/2014 594 0 761 1,077 0 0 0 0.00 -1,077 4/30/2014 536 0 522 873 0 0 0 0.00 -873 5/31/2014 443 37 437 762 0 0 0 0.00 -762 6/30/2014 364 191 488 868 0 0 0 0.00 -868 7/31/2014 216 591 539 1,153 0 0 0 0.00 -1,153 8/31/2014 209 339 384 795 0 0 0 0.00 -795 9/30/2014 229 71 323 506 0 0 0 0.00 -506 10/31/2014 222 67 330 499 0 0 0 0.00 -499 11/30/2014 399 425 368 1,070 0 0 0 0.00 -1,070 12/31/2014 352 430 370 1,027 0 0 0 0.00 -1,027 Average: 2014 410 179 495 908 0 0 0 0.00 -908 Cumulative: mstb mstb mmscf mrb mstb mmscf mrb mrb 31 -Dec -14 2,702 2,467 2,780 7,003 3,020 324 3277 0.47 -3,726 Page 1 Exhibit 4-E Static Pressure Data Sag River Oil Pool FL Fluid Level PBU Pressure Build Up PFO STATE OF ALASKA PP Pump Pressure SBHP Shut -In Bottom Hole Pressure ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. O rator: Hibor Alaska, I.I.C. 12. Address: 3600 Centerpoint Dr, Anchorage AK 99503 3. Unit or Lease Name: Milne Point 4. F Id and Pool: Sag River Oil Pool 1 5. Datum Reference: 8750' SS 6. Oil Gravity: API -34 T Gas Gravity: Air= 0.65 e. Well Name antl Number: 9. API Number 50-XXX-XXXXX-XX-XX 10. Oil (0) 11. AOGCC Pool or Gas (G) Code 12. Final Test Dale 13. Shut -In 14, Press. 75. B.H. 16. Depth Tool 17. Final 76. Datum Tme, Hours Sum. Type Temp. TVD. Pressure at TVD. (see Tool Depth (Input) Insirudmna for -deal 19. Preswre 20. Comments Zone Gradient, psVll. Preswre at Datum (-I) MPF -33A 50-500-29226-89-01 Unknow in Type 525150 4/15/2014 17,650 SBHP 218 8,382 4,171 8750 0.627 4,402 MPF -33A 50-500-29226-89-01 Unknow In Type 525150 3/17/2014 16,964 SBHP 221 8.455 4,135 8750 0.400 4,253 Grad = 0.3996 psilft MPF -33A 50-50029226-89-01 Unknow In Type 525150 2/7/2014 16,051 SBHP 221 8,455 4,418 8750 0.403 4,537 Grad = 0.4025 psitft MPF -33A 50-500-29226-89-01 Unknow In Type 525150 3/17/2014 SBHP 212 8,107 3,996=87500.384 4,253 MPF -33A 50-500-29226-89-01 Unknow n Type 525150 4/14/2014 17 827 SBHP 219 8,455 4,199 4312 MPF -73A 50-500-29227-44-01 INJ 525150 7/5/2014 14 928 SBHP 214 8,643 4,6794.725 Grad = 0.44 sVft SAG 4 414 21. All tests re ded herein were made in accordance with thea liable rules, regulations and inatmctions of the Alaska Oil and Gas Conservation Commissbn. I hereby certify that the foregoing is true and correct to the best of my k—led e Signature The Reservoir En ineer Printed Name Anthony McConkey Date 6/30/2015 FL Fluid Level PBU Pressure Build Up PFO Pressure Fall Off PP Pump Pressure SBHP Shut -In Bottom Hole Pressure Exhibit 4-F Injection Rate and Pressure Data Milne Point Field Sag River Pool Well MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A MPF -73A WH Pressure Month Avg (psi) 1/1/2014 2/1/2014 3/1/2014 4/1/2014 5/1/2014 6/1/2014 7/1/2014 8/1/2014 9/1/2014 10/1/2014 11/1/2014 12/1/2014 Days Operating 0 0 0 0 0 0 0 0 0 0 0 0 Inj Vol Calc. (BBL, Injection Rate Avg. MCF) (BWPD) Section 5 Production/Injection Well Surveillance List of Exhibits Milne Point Surveillance 1/1/2014 —12/31/2014 5-A Production/Injection Well Surveillance As per Conservation Order 205 (Kuparuk River Oil Pool) and Order 477 (Schrader Bluff Oil Pool), the Milne Point Operator runs injection surveys on at least one third of the existing online multiple zone injectors annually and on new multiple zone injectors. In 2012 AOGCC verified that for Milne Schrader these surveys would only apply to online unregulated injectors. There were 27 existing Kuparuk multi -zone injectors in 2014. Nine injection surveys were obtained in 2014. All of these injection surveys were performed in multi -zone injectors. There were 14 existing unregulated Schrader Bluff multi -zone injectors in 2014, seven of which were shut in all year. Injection surveys were run in 2 of the 7 online unregulated Schrader Bluff multi -zone injectors. An injection survey was run in an unregulated Schrader producer (MPS -08) with Borax logging for MBE analysis/diagnostics. No injection survey was needed in the Sag River Oil Pool because no injectors were online during 2014. Since the majority of producers at Milne Point are completed with ESPs or jet pumps which preclude logging below the pump while on production, few production logs are run. No production logs were run in Kuparuk wells in 2014. There was a production log run in MPH -19 in order to determine where the high watercut production was stemming from along the lateral, the data was inconclusive due to a high degree of slugging during the operation. Exhibit 5-A is a summary of the Milne Point field well surveillance performed in 2014 on both producers and injectors. Exhibit 5-A Milne Point Unit 2014 Surveillance Kuparuk River Oil Pool Schrader Bluff Oil Pool Sw Name Reservoir Well Type Rec Date Log Type Field Analyis Final Determination IPROF indicated 100% slow 100%C into C -sands. Inline spinner 0% B icame back plugged with MPB-05A IKUP INJ 9/4/2014 STP/IPROF �schmoo. 19% C 6% B 32% A3 43% A2 Field splits: 19% C, 6% B, MPC -15 KUP INJ 9/25/2014'STP/IPROF 32%A3,43%A2 8.7% C Field made note that 7.8% B "most" of injection was 66.0% A3 entering A3 sand, actual 19.8% A2 MPC -39 KUP INJ 10/14/20141STP/IPROF splits were inconclusive. 16% C 56% A3 28% A2 Field splits: 17.6% C, 56.5% MPC -42 KUP INJ 9/2/2014 STP/IPROF A3, 25.9%A2. 100% Injection going into upper perforations (C - sand). Unable to log B -sand 100% C perforations due to 0% B fill/schmoo below C -sand MPE-23 KUP INJ 9/3/2014'STP/IPROF perfs. 28.2% A3 Field Splits: 34.2%A3,4.4% 7.7%A2 MPF -91 KUP INJ 8/1/2014,STP/IPROF A2, 61.4%A1 64.1%A1 5%C 0% B 10% A3 Field splits: 0% C, 0% B, 5% 85%A2 MPL-08 KUP INJ 8/10/2014'STP/IPROF A3, 95%A2, 0% Al 0%A1 Field splits: 100% [Inconclusive] MPL-15 KUP INJ 8/12/2014 STP/IPROF A/A3/A2/A1 (Inconclusive) Exhibit 5-A Milne Point Unit 2014 Surveillance Kuparuk River Oil Pool Schrader Bluff Oil Pool Sw Name Reservoir Well Type Rec Date Log Type Field Analyis Final Determination 0% B Field splits: 2% B, 95% 100%A3/A2 MPL-16 KUP INJ 8/12/2014 STP/IPROF A3/A2, 3%A1 0%A1 0% Nb Field Splits: 63% OA Upper 63% OA (Upper) Lobe, 37% OA Lower Lobe, 37% OA (Lower) MPJ -15 SCHRADER INJ 9/18/2014 STP/IPROF No injection in N or OB. 0% OB 'Field splits: 8% OA Upper Lateral, 92% OB Lower 8% OA MPS -04 SCHRADER INJ 7/22/2014 STP/IPROF Lateral 92% OB Inconclusive due to slugging MPH -19 SCHRADER PROD 8/4/2014 PPROF w/ N2 during logging. [Inconclusive] 22.2% distributed from 5200-6750' MD. STP/IPROF/PN Field splits: 80% entering 77.8% between 6756'- 756' - MPS -08 1 MPS -08 SCHRADER PROD 8/4/2014 L/Borax formation at 6760' MD. 6765' MD. Section 6 Shut in Well Status List of Exhibits Milne Point Shut in Well Status 1/1/2014 — 12/31/2014 6-A Exhibit 6-A 2014 Shut -In Wells Milne Point Unit Sw Name Reservoir Reason for Well Current Mechanical Condition of Nkll, including integrity Future Utility Plans & Comments u 4 t 'ss es' Possibilities' A Currently has T)dA communication through broken GLV in 3 Although well has TAA communication, WELLS has suggested that it could still MPB-03 Kuparuk GLM#1. be produced (leak is essentially no different than having a S/O in that mandrel). It is SI due to the high GOR and its proximity to gas injector MPE-02. MPB-04A Kuparuk A Operable well, SI due to high gas rates - Facility unable to handle extra ass 6 Plan to reactivate well when WAG system is brought back online at C -pad. MPB-06 Kuparuk D Surface casing leak. 3 Cost is approximately. $4MM for a SC repair. Not economic on a —100 bopd well. D Tubing leak; IBP set in well Feb 2006 to secure. 5 High GOR well. Needs permanent flowlines installed and gas lift line is blinded. MPB-07 Kuparuk Diagnostics determined potential source of pressure from packer leak. Well has been secured Well will have reservoir P&A MPB-08i Kuparuk E 1 4 Well does not support any producers. No flowlines orwellhouse. MPB-11 i Kuparuk D Tubing leak; well secured with sand plug. 1 Need to fix leaking permanent patch and perform FCA. MPB-121 Kuparuk E No known problems. 6 Well supports MPB-03. If MPB-03 ever comes back online, then B-1 2i will be MPB-14i Kuparuk E No known problems. 3 MPB-20's conversion to an injector has replaced the need for this well to be on niection. No current plans to brina the wall BOI MPB-17i Kuparuk E No mechanical problems. 3 Wellhouse and flowlines removed. Quick communication with producer. Evaluate MPB-19 Kuparuk B No known problems. 3 Wellhouse and flowiines removed. GL well. High water cut producer. Possible frac A Cement Packer Squeeze repaired the TAA communcation in 6 Producer is in the same HU as gas injector E-03. Well comes online with very MPB-23 Kuparuk high GOR. Will likely be used for gas flowbacks if Mine encounters a gas May 2012. MPB-25i Kuparuk E No known problems. 6 Ready to tum on when offset producer comes back on (E-18) MPB-27LSi Schrader E No known problems. 3 MPB-27LSi was shut in in April 2012 after offset producer MPE-30A was shut in and P&Ad due to sub urface subsidence damae MPC -081 Kuparuk E Offset to SA MPL-06, high BHP 6 Return to water injection when BHP is reduced, may try bringing BOI to support MPC -111 Kuparuk E No wellhouse, no flowlines 3 Further use as an injector not required while no offset producers on line. MPC-12Ai Kuparuk D Well suspended 7/13/03. Secured with CIBP and FP with dieseL 4 Wellbore lost during coiled tubing sidetrack. MPC -16 Kuparuk A Well suspended 10/27/93. Pulled completions and set 2 4 High GOR from E-03 gas breakthrough. MPG -17i Kuparuk D Leak in 9 5/8' casing to surface 6 scoping out non -rig remedial actions MPC -20 KuparukB No wellhouse, no flow Ines 3 High water mt. Perfd without good logs. Wellhouse and flowlines removed. Would need WSO MPCFP-02i Kuparuk E No known mechanical problems 3 Thief zone directly to offset producers. Evaluate Sag/Schrader potential. MPD -01 Ku aruk C Dead ESP completion downhole, no support to block 5 No support to block. No flovAnes from D pad. Plan to P&A in the future. MPD -02A Kuparuk B Well has TxiA communication. Well resecured post SBHP 5 High water at well. No flowlines from D pad. Plan to P&A in the future. MPE-08 Kuparuk D Failed ESP 1 Possible donor well bore. MPE-16i KuparukE Long term shut in 1 MPE-16 supports MPB-06 which is shut-in for surface casing leak. MPE-16 will rema n shut- n unt I B-0 comes back on line. MPE-18 Kuparuk 0 No Surface Kit with ESP Completion Downhole 3 High WC Well on MPE Pad goes w/o surface kit MPE-21 Schrader E ESP failed 3 Wellhouse and flowlines removed MPE-25A Schrader E Injector in a highly compartmentalized area 3 MPE-28 Schrader D ESP failed, leak in surface casing 3 MPE-30A Schrader C Suspended well 728/2012 4 Severe rasing budding MPE-33 Schrader C ESP failed; no surface casing and liner has no cement 3 Wellhouse and flowlines removed. Possible conversion to injection. MPF -17i Kuparuk D Tubing integrity problem 1 RWO needed to replace tubing. Requires new seismic to understand HU MPF -33A Sag River D Stuck jet pump 2 SA due to stuck jet pump. RWO planned in 2014 MPFdi i Kuparuk E 8/1 for pressure management 6 Drilled as a producer. High water saturation so converted to injection. No response MPF-73Ai Sag River E S/I for pressure management 6 Plan to POI in 2014 post MPF-33A's RWO. Exhibit 6-A 2014Shut-InWells Milne Point Unit Sw Name Reservoir Reasonfor Well Shutan' Current Mechanical Condition of Nall, including integrity issues' Future Utility Plans & Possibilities3 Comments MPF -80 Ku aruk E Suspended well June 2011. Well plugged 4 Suspended well June 2011 MPF -90 Ku awk C No producer connections 1 S/I for lack ofpmducerconnections MPG -04 Schrader C ESP failed 3 Marginal economics for repair- may re-evaluate in 2015. MPG -08A Schrader C ESP failed 1 High sand production. Intervention under evaluation. MPGA 1 Schrader C ESP failed 3 Bottom Hole location replaced MPG -12 Schrader C ESP failed 3 Bottom Hole location replaced. No surface casing. MPH -01 Schrader C ESP failed 1 Well house has been removed. MPH -02 U nu A No known problems. Has a temp drive for ESP 3 Oil sample retrieved during 2006 but no production to plant MPH -03 Schrader C No known problems. ESP still functional. 1 MPH -04 Schrader C Failed ESP 1 Low flow, considering for sidetrack MPH -07A Schrader C Failed ESP 1 Low rate producer due to compartmentalization - unable to provide injection MPH -09 Schrader 0 Suspended, Hole in rasing at 311' 5 P&A in progress. MPH -10 Schrader D ESP failed, Hole in casing 3 MPH -11 Schrader E No known problems 6 Injector will be put back online with offset producers MPH -13A Schrader D Screens Breached, MBE with supporting injector, subsidence I dam... 5 Solids production from breached screen, MBE vvth injector. Shallowsubsidence, hiQh orioritv candidate for P&A, MPI -01 Schrader C ESP failed 3 Flowiine removed in '98. Solids producer. Bottom hole location replaced by 1-15. MPI -05 Schrader E No offset production 6 N -sand only injector. No offset producers completed in the N -sand. MPI -06 Schrader C ESP failed 3 Failed ESP and MBE to injector, high WC if POP'd MPI -11 Schrader D Surface Casing Leak 2 Repair requires excavation or RWO. MPI-13SS Schrader B No known problems 6 High pressure in southern offset SI producer. Will put back online with Northern offset producer MPJ -02 Schrader E No offset production 6 N -sand only injection w/ no offset N -sand production. May place on injection if G - MPJ -04 Schrader C ESP failed 1 Low flow, considering for sidetrack MPJ -05 Schrader C ESP Falure- uneconomic for ESP swap. 2 Planning on converting to injector in 2015. MPJ -07 Schrader D ESP failed; TxVxOA 3 Bottom hole location replaced by 1418 MPJ -12 Ku awk C ESP failed 1 No surface facilities. Evaluate potential sidetrack targets. MPJ -16 Ku aruk E No known problems 1 No surface facilfties. Evaluate potential sidetrack targets. MPJ -20A Schrader E Injector with MBE and offset producers SI 6 Injector will be put back online with offset producers MPJ -21 Schrader C ESP failed 3 RDS well no surface csg. Bottom Hole location replaced by J-26 MPJ -23 Schrader C MBE with supporting injector 3 MPJ -24 Schrader E Fill in casing, unsuccessful FCO 1 MPK-09 Ku awk C ESP failed 1 Needs RWO to replace failed ESP MPK-13 Ku amk C ESP failed 1 Needs RWO to replace failed ESP MPK-18A Ku aruk E Conosion from source water 1 RWO to replace tubing is uneconomic. MPL-06 Ku amk D Reservoir section abandoned 4 Well suspended during 5/2012 RWO. Reservoir section abandoned. MPLA0 Ku amk E No known mechanical problems 1 Intervention under evaluation MPLA 7 Kuparuk D ESP failed. Low remaining reserves 1 Low remaining reserves. Evaluate potential gas storage well or Kuparuk sidetrack. MPL-21 Ku amk E High pressure block. 1 Intervention under evaluation MPL-34 Ku aruk E Suspended 12/1/2008. High pressure block. 4 No indication ofoommunicating with surrounding producers. MPL-35A Schrader C Attempt to produce from NW Schrader O -sands. Lav rate, ESP failed 1 No plans fixing well. Planning on drilling grass mots wells to target NW Schrader area My be onoortundv for STAnAll drill no In future MPL-37A Schrader C Dead ESP, no other mechanical issues 1 Planned sidetrack for NW Schrader development MPL-39 Kupamk E No knovm mechanical problems 2 Plan to convert to producer. Brought online very briefly in November 2014 (<l day POP time) using 'poor boy' jet pump lift. Considering replacing JP system with an ESP MPL42 Ku amk D Slow TAA communication on gas injection 1 Intervention underevaluation MPL-45 Schrader C ESP failed. 1 Lav productMty. Evaluate conversion to jet pump or potential Schrader sidetrack. Exhibit 6-A 2014 Shut -In Wells Milne Point Unit S. Name Reservoir Reason for Well S t Current Mechanical Condition of Well, including integrity es' Future Utility Plans & Possibilities' Comments MPS -01 BLS Schrader D No integrity issues 3 Injector has MBE MPS -03 Schrader A No integrity issues 2 SI due to high GOR; may have injection support now to bring well online MPS -06 Schrader E No integrity issues 6 No offtake in 2012, plan to return to injection when offset producers are online MPS-07LS Schrader D Suspended 11/17/2011. Surface casing leak 4 Suspended Nov. 2011 MPS-07SS Schrader D Suspended 11/17/2011. Surface casing leak 4 Suspended Nov. 2011 MPS -08 Schrader D Well produces large volume of solids which upsets the plant. 2 Ran IPROFAMFL and caliper to locate potential screen breach. Planning on setting patch over screen breach, MPS-09LS Schrader D Surface casing Issue 3 MPS-09SS Schrader D Surface casing Issue 3 MPS-10ALS Schrader D Operable with String communication 3 Intervention under evaluation MPS-10ASS Schrader D Operable with String communication 3 Intervention under evaluation MPS-13LS Schrader D Matrix Bypass Event (MBE) present in well 2 Intervention planned - will likely pump MBE treatment in future. MPS -21 Schrader E No known problems, Cement over perforations 1 Lost CT under -reamer in hole MPS -22 U nu C No known problems 1 Low Pl. MPS -24 Schrader C Produces a lot of solids, part of a failed sand consolidation treatment with 8P, Has an MBE Vhth offset producer S-1 4. 3 No plans on fixing well, may consider If fixing sending problem in S-08 and/or S - 03 is successful. MPS -27 Schrader D Integrity cencems 1 No issues but SI for uncertainty about integrity ofthe well MPS -32 Schrader D Casing leak 1 Intervention under evaluation MPS-33ASS Schrader E No integrity issues 1 MBE to producer, potential MBE treatment candidate MPS -37 Ugnu D Pump problem. 3 Long tens shut in well. MPS -39 Ugnu D Pump Failed. 3 Will attempt to re -activate after GNI facility is finished in 2015. MPS -41A Ugnu D Suspended with cement. 4 Unable to fish tubing. MPS43 U nu D Pump Failed. 3 No anent plans to re -activate well, may do so after successful repair of S-39. Reasons for Well ShLA4n A. High GOR, currently uncompetitive to produce due to facility constraints, no known mechanical problems B. High water, currently uneconomic to produce, no known mechanical problems C. Low production rate, no known mechanical problems D. Mechanical problems E. Other (Specify under comments) Current Mechanical Condition Briefly describe the current mechanical condition ncIuding the condition of installed tubing and casing strings. Future Utility 1. Evaluating remedial, sidetrack and/or redrill opportunities 2. Remedial well work planned 3. Long lerm Shutan well/No immediate plans 4. Suspended well S. P&A planned 6. Other (Specify undercomments) Section 7 Milne Point Well Testing with ASRC Unit 5 and Weatherford Gen 2 (VSRD) Summary List of Exhibits Well Test Frequency 7-A Milne Point Well Testing Milne Point primarily utilizes on -pad separators for well testing. The pad separators at C, E, F, H, K and L -Pads employ volumetric, vessel -based gas-liquid separation. Separators at I and J -Pads employ centrifugal separation, while the separators at B, G, and S -Pads are multiphase meters, aka Alpha "VSRD" (Venturi, Sonar, Red Eye, and Densitometer). Thus, a variety of metering technologies are employed across Milne Point including: - Turbine positive -displacement, Micro Motion coriolis meters or Venturi/Sonar meters for liquid flow rate. - Phase Dynamics or Red Eye watercut meters on the separator liquid legs. - Turbine, Micro Motion coriolis meters or densitometers for gas flow rate. Wells are automatically routed into test on a rolling schedule, such that a well is always being tested on every pad with in-place testing facilities. Test duration is at least 6 hours, not including the necessary purge time to flush the lines and vessel. Exhibit 7-A provides information on the well tests conducted for consideration in production allocation during 2014. The services of portable test separators, provided by contractor ASRC, are utilized on an ad-hoc basis whenever there are concerns about individual pad separators or to verify readings from the fixed pad separators. As part of the growing efforts to improve confidence in test separation systems across operations on the North Slope, Milne Point is also employing the use of new types of multi -phase meters, as well as proper use of chemical additives such as emulsion breaker. At Milne Point, Weatherford multiphase meters, aka Alpha VSRD (Venturi, Sonar, Red Eye, Densitometer), were installed at G and S -Pads in 2009 and 2011 respectively. For the 2014 year, all G -Pad and S -Pad wells were allocated from the VSRD well tests. The VSRD meter at G -Pad is not maintenance free; however, some issues with the MVT puck (Multi -Variable Transmitter) occurred between May and August 2014. Weatherford has since corrected the issue and the pad has resumed allocating off ofthe VSRD. Milne Point engineers review well test quality on a daily basis and work with operations on the North Slope to get meters fixed when needed. A Weatherford multiphase meter (VSRD) was installed at MPS -Pad in March 2011 and commissioned for allocations in June 2011. All MPS -Pad wells are allocated from the VSRD. The gross fluid and gas rates shown in Figure 7-C were repeatable and reliable in 2013. However, as shown in Figure 7-C, the Red Eye watercut meter required maintenance and was not used for allocations in January and February 2013. After one of the channels on the Red Eye watercut meter was turned off, the readings were once again reliable. The Red Eye is still verified against periodic water shake -outs on wells showing significant watercut changes. During a scheduled 2011 inspection of B -Pad's test separator, internal corrosion was found. The separator was taken offline in June 2011. Since taking the separator vessel offline, the pad has been relying on ASRC portable tests for production allocation. Following the success of the VSRD's at both G & S -pads, work began in 2013 to install a VSRD multiphase meter on B -Pad. While the meter has been successfully installed at B -Pad, work is on-going to calibrate the B -Pad VSRD meter to the three-phase production rates at B -Pad. The main problems with the new VSRD was related to the constant `slugging' on the B -pad wells (B -pad is all gas lift and tends to produce the highest GOR out of any other pad at MPU). The slugging caused vibrational damage to the systems, primarily the RedEye watercut meter. Weatherford created new RedEye probes specially designed for Milne Point B -pad. The new probe was planned to be installed in the fall of 2014, however the equipment was then damaged during the shipping process. Another probe is under development as of December 2014. Most of B -Pad's production was allocated from the portable ASRC test separator, although some tests have been utilized for allocation in between times of the equipment malfunctioning. I and J pads currently use Kvaerner-Hydrocyclone separators. The separators have had some issues with accurate testing as a result of oversized gas orifices and gross fluid Coriolis meters. ASRC Unit #5 was used to allocate welltests throughout 2014. As of December 2014, Hilcorp is in the process of correctly calibrating/revising the Kvaerner meters in order to maintain consistent and reliable tests at I and J pads. Hilcorp also plans to purchase a portable separator in the future that will be designed for testing throughout the field for future separator/welltest diagnostic work. ASRC Unit #5 Operational and Performance Issues ASRC Unit 5 is a portable well test unit that uses FMC Technologies Enhanced Multiphase System (EMS) to measure well production. The EMS is comprised of a venturi meter and capacitance and conductance electrodes coupled with a cyclonic pre -separator allowing partial separation and metering in high gas volume fraction wells. The unit was used at the Milne Point Field throughout 2008 under temporary AOGCC approval and approved for permanent use at Milne Point on December 30, 2008. ASRC Unit 5 underwent a trial period in early 2008 where piggy back testing was conducted with an established gravity test separator, ASRC Unit 1. The resulting test data from Unit 5 was compared to Unit 1 tests, manual fluid samples and historic field well tests. In this way, it was determined that Unit 5 measures total liquid volume within f 10% and water cut with an uncertainty band of f2.5 to 5%. Following the trial period, Unit 5 was accepted as a full time portable test separator at Milne Point, and it began autonomous testing across the field. Work is ongoing with ASRC to continue to improve the accuracy of Unit 5 with a focus on metering gross fluid rates, water cuts and gas volumes. Exhibit 7-A 2014 Well Testing Milne Point Unit 2014 Well Average Required Tests/ Month Days On Prod. Tests / Average Tests / Month MPB Month Field total All** 4.2 KUP All 4.5 SBF All 3.4 SAG All 3.0 Reservoir Pad 0.0 KUP B 0.1 KUP C 5.3 KUP E 3.7 KUP F 3.7 KUP H 5.1 KUP 1 3.4 KUP K 9.8 KUP L 5.1 SBF C 0.0 SBF E 4.2 SBF G 6.5 SBF H 2.0 SBF 1 0.4 SBF 1 0.3 SBF S 7.1 SAG C 3.8 SAG F 0.0 SAG K 1.7 *Average Tests / Month calculated as total number of tests divided by days operating, multiplied by 30.5 days per month. **Field total data excludes Ugnu wells Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month MPB MPB-09 KUP 1 78 0 0.0 MPB MPB-10 KUP 1 353 1 0.1 MPB MPB-15 KUP 1 364 1 0.1 MPB MPB-16 KUP 1 358 2 0.2 MPB MPB-21 KUP 1 345 2 0.2 MPB MPB-22A KUP 1 355 1 0.1 MPC MPC -01 KUP 1 364 73 6.1 MPC MPC -03 KUP 1 360 74 6.3 MPC MPC -04 KUP 1 352 57 4.9 MPC MPC -05A KUP 1 101 28 8.5 MPC MPC -07 KUP 1 362 27 2.3 MPC MPC -09 KUP 1 281 55 6.0 Exhibit 7-A 2014 Well Testing Milne Point Unit Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month MPC MPC -13 KUP 1 324 87 8.2 MPC MPC -14 KUP 1 359 35 3.0 MPC MPC -21 KUP 1 356 86 7.4 MPC MPC -22A KUP 1 361 69 5.8 MPC MPC -23 SBF 2 354 44 3.8 MPC MPC -24A KUP 1 362 78 6.6 MPC MPC -26 KUP 1 360 45 3.8 MPC MPC -40 KUP 1 356 39 3.3 MPC MPC -43 KUP 1 334 57 5.2 MPE MPE-04 KUP 1 345 37 3.3 MPE MPE-06 KUP 1 365 53 4.4 MPE MPE-09 KUP 1 363 37 3.1 MPE MPE-10 KUP 1 365 48 4.0 MPE MPE-11 KUP 1 329 54 5.0 MPE MPE-14A KUP 1 365 35 2.9 MPE MPE-15 SAG 2 260 42 4.9 MPE MPE-19 KUP 1 192 29 4.6 MPE MPE-20A SAG 2 365 52 4.3 MPE MPE-22 KUP 1 365 36 3.0 MPE MPE-24A SAG 2 187 19 3.1 MPE MPE-31 SAG 2 363 51 4.3 MPE MPE-32 SAG 2 285 35 3.7 MPF MPF -01 KUP 1 98 13 4.0 MPF MPF -05 KUP 1 361 46 3.9 MPF MPF -06 KUP 1 365 47 3.9 MPF MPF -09 KUP 1 355 46 4.0 MPF MPF -14 KUP 1 365 44 3.7 MPF MPF -18 KUP 1 354 43 3.7 MPF MPF -22 KUP 1 355 43 3.7 MPF MPF -25 KUP 1 355 44 3.8 MPF MPF -29 KUP 1 365 42 3.5 MPF MPF -34 KUP 1 354 45 3.9 MPF MPF -37 KUP 1 365 46 3.8 MPF MPF -38 KUP 1 365 44 3.7 MPF MPF -45 KUP 1 355 45 3.9 MPF MPF -50 KUP 1 365 43 3.6 MPF MPF -53A KUP 1 287 39 4.1 MPF MPF -54 KUP 1 337 42 3.8 MPF MPF -57A KUP 1 291 31 3.2 MPF MPF -61 KUP 1 355 45 3.9 MPF MPF -65 KUP 1 365 49 4.1 MPF MPF -66A KUP 1 365 42 3.5 MPF MPF -69 KUP 1 365 44 3.7 MPF MPF -78A KUP 1 273 31 3.5 Exhibit 7-A 2014 Well Testing Milne Point Unit Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month MPF MPF -79 KUP 1 365 49 4.1 MPF MPF -81 KUP 1 247 32 4.0 MPF MPF -86 KUP 1 290 36 3.8 MPF MPF -87A KUP 1 365 49 4.1 MPF MPF -93 KUP 1 225 18 2.4 MPF MPF -94 KUP 1 296 37 3.8 MPF MPF -96 KUP 1 362 39 3.3 MPG MPG -02 SAG 2 364 86 7.2 MPG MPG -14 SAG 2 364 78 6.5 MPG MPG -15 SAG 2 267 82 9.4 MPG MPG -16 SAG 2 332 75 6.9 MPG MPG -18 SAG 2 300 27 2.7 MPH MPH -05 KUP 1 345 58 5.1 MPH MPH -08B SAG 2 354 5 0.4 MPH MPH -16 SAG 2 348 52 4.6 MPH MPH -18 SAG 2 216 10 1.4 MPH MPH -19 SAG 2 186 7 1.1 MPI MPI -03 SAG 2 354 4 0.3 MPI MPI -04A SAG 2 282 3 0.3 MPI MPI -07 SAG 2 277 4 0.4 MPI MPI -12 SAG 2 24 1 1.3 MPI MPI -14 SAG 2 134 3 0.7 MPI MPI -15 SAG 2 364 4 0.3 MPI MPI -17 SAG 2 235 2 0.3 MPI MPI -19 SAG 2 364 4 0.3 MPJ MPJ -01A SAG 2 364 4 0.3 MPJ MPJ -03 SAG 2 346 4 0.4 MPJ MPJ -06 KUP 1 364 4 0.3 MPJ MPJ -08A SAG 2 361 40 3.4 MPJ MPJ -09A SAG 2 259 4 0.5 MPJ MPJ -10 KUP 1 364 4 0.3 MPJ MPJ -25 SAG 2 364 42 3.5 MPJ MPJ -26 SAG 2 360 3 0.3 MPK MPK-02 KUP 1 259 3 0.4 MPK MPK-05 KUP 1 19 6 9.6 MPK MPK-06 KUP 1 352 136 11.8 MPK MPK-17 KUP 1 363 76 6.4 MPK MPK-30 KUP 1 365 115 9.6 MPK MPK-33 SBF 2 294 82 8.5 MPK MPK-33 KUP 1 214 12 1.7 MPK MPK-34 #N/A #N/A 112 76 20.7 MPK MPK-37 KUP 1 333 0 0.0 MPK MPK-38 KUP 1 200 73 11.1 MPL MPL-01A KUP 1 291 78 8.2 Exhibit 7-A 2014 Well Testing Milne Point Unit Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month MPL MPL-02A KUP 1 201 41 6.2 MPL MPL-03 KUP 1 235 56 7.3 MPL MPL-04 KUP 1 364 63 5.3 MPL MPL-05 KUP 1 321 54 5.1 MPL MPL-07 KUP 1 364 77 6.5 MPL MPL-11 KUP 1 364 44 3.7 MPL MPL-12 KUP 1 364 54 4.5 MPL MPL-13 KUP 1 364 70 5.9 MPL MPL-14 KUP 1 362 48 4.0 MPL MPL-20 KUP 1 364 86 7.2 MPL MPL-25 KUP 1 365 47 3.9 MPL MPL-28A KUP 1 359 55 4.7 MPL MPL-29 KUP 1 365 32 2.7 MPL MPL-36 KUP 1 316 48 4.6 MPL MPL-40 KUP 1 235 40 5.2 MPL MPL-43 KUP 1 364 63 5.3 MPS MPS -05 SAG 2 311 57 5.6 MPS MPS -12 SAG 2 231 25 3.3 MPS MPS -17 SAG 2 226 46 6.2 MPS MPS -19A SAG 2 264 48 5.5 MPS MPS -23 SAG 2 306 85 8.5 MPS MPS -25 SAG 2 305 89 8.9 MPS MPS -28 SAG 2 315 82 7.9 MPS MPS -29 SAG 2 363 92 7.7 MPS MPS -35 SAG 2 64 0 0.0
