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HomeMy WebLinkAbout2013 Milne Point Unit Milne Point Unit Waterflood and Reservoir Surveillance Report for Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool January through December, 2013 Issued: March 31, 2014 Sections and Exhibits Introduction Overview 1 Section 1: General Information Exhibits 1A – 1E Kuparuk River Oil Pool 2 Section 2: Kuparuk River Oil Pool Exhibits 2A - 2G Schrader Bluff Oil Pool 3 Section 3: Schrader Bluff Oil Pool Exhibits 3A – 3H Sag River Oil Pool 4 Section 4: Sag River Oil Pool Exhibits 4A – 4G Production/Injection Surveillance Logs 5 Section 5: Production/Injection Well Surveillance Exhibits 5A Shut in Well Exhibit 6 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 – 7C ANNUAL RESERVOIR SURVEILLANCE REPORTS MILNE POINT UNIT KUPARUK RIVER OIL POOL SCHRADER BLUFF OIL POOL SAG RIVER OIL POOL JANUARY - DECEMBER 2013 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 2013. 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.  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 Milne Point Unit Map 1-A Overview Statistical Summary 1-B Kuparuk Pressure Map 1-C Schrader Bluff Pressure Map 1-D Sag River Pressure Map 1-E Overview Exhibit 1-A shows the participating areas of the three waterflood projects in the Milne Point Unit: the Kuparuk River Oil Pool, the Schrader Bluff Oil Pool and the Sag River Oil Pool. 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 WaterTM is a polymer additive to injection water that alters sweep patterns within the reservoir with the purpose of improving oil recovery. A Bright WaterTM 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 WaterTM 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 WaterTM 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 WaterTM 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 WaterTM , MPF-84, MPF-88, & MPF-91. A 2013 review of the 2009 and 2012 Milne Kuparuk Bright WaterTM 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. No drilling activity took place in 2013 in either the Kuparuk or the Schrader Bluff formations. In 2013, 11 RWO’s (rig workovers) were completed in the Schrader Bluff. This had a positive impact on production at the end of 2013. In 2013, 19 RWO’s were completed in the Kuparuk. Exhibit 1-B 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 2013, field production averaged 18.6 MBOD, 11.7 MMSCFD (GOR 622 SCF/STB) and 64.8 MBWD (water cut 78%). Waterflood injection during this period averaged 78.2 MBWD with 2.8 MMSCFD of gas injection. The volumes given above include production from the Ugnu Tract Operations (Heavy Oil Pilot). As of December 31, 2013, cumulative water injection in the Kuparuk River Oil Pool was 493.5 MMSTB, while cumulative gas injection was 105.2 BSCF. Cumulative production was 241.6 MMSTB oil, 134.5 BSCF gas, and 316.1 MMSTB water. From first production to December 31, 2013, cumulative production exceeded injection by 71.1 MMRB. As of December 31, 2013, cumulative water injection in the Schrader Bluff Oil Pool was 149.6 MMSTB and cumulative gas injection in the Schrader Bluff Oil Pool was 220 MMSCF. Cumulative production was 70.5 MMSTB oil, 42.0 BSCF gas, and 61.6 MMSTB water. From first production to December 31, 2013, cumulative production has exceeded injection by 29.3 MMRB. Cumulative water injection in the Sag River Oil Pool from startup through December 2013 was 3.0 MMSTB, while cumulative gas injection was 324 MMSCF. Cumulative production was 2.6 MMSTB oil, 2.6 BSCF gas, and 2.4 MMSTB water. As of December 31, 2013, cumulative production exceeded injection by 3.5 MMRB. Exhibits 1-C, 1-D, and 1-E provide an aerial view of reservoir pressures throughout the Kuparuk River, the Schrader Bluff, and the Sag River Oil Pools. Milne Point Unit Boundary Milne Point Sag River PA Milne Point Kuparuk PA Milne Point Schrader Bluff PA 1 1 2 mi 0 Milne Point Unit Boundary and Kuparuk, Schrader Bluff And Sag River PA’s, 2011 2013 Exhibit 1-B Milne Point Unit 2013 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS Kuparuk Schrader Sag River Bluff River Oil Pool Oil Pool Oil Pool As of 12/31/2012 Producers 78 34 2 Injectors 51 38 1 - WAG 39 0 0 - Water Only 11 38 1 - Gas Only 1 0 0 As of 12/31/2013 Producers 78 39 2 Injectors 49 39 1 - WAG 36 0 0 - Water Only 11 39 1 - Gas Only 2 0 0 Production Well Status in 2013 - Newly Drilled 0 0 0 - Sidetracked or Redrilled 0 0 0 Gas Injection Well Status in 2013 - Newly Drilled 0 0 0 - Sidetracked or Redrilled 0 0 0 WAG Injection Well Status in 2013 - Newly Drilled 0 0 0 - Sidetracked or Redrilled 0 0 0 Water Injection Well Status in 2013 - Newly Drilled 0 0 0 - Sidetracked or Redrilled 0 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-B (continued) Milne Point Unit 2013 OVERVIEW STATISTICAL SUMMARY PRODUCTION/INJECTION STATISTICS Kuparuk Schrader Sag Ugnu River Bluff River Trial Oil Pool Oil Pool Oil Pool Cumulative Production Through 12/31/2013 Oil (MSTB)241,648 70,496 2,553 24 Gas (MMSCF)134,491 42,016 2,600 0 Water (MSTB)316,131 61,605 2,401 174 Cumulative Injection Through 12/31/2013 Water (MSTB)493,482 149,616 3,020 0 Gas (MMSCF)105,224 220 324 0 Cumulative Voidage Balance Through 12/31/2013 Cum. Production (MRB)662,410 180,726 6,776 0 Cum. Injection (MRB)591,284 151,445 3,309 -174 Over/Under (MRB)-71,126 -29,281 -3,468 -174 AVERAGE RATE 2013 Production: Oil (MBD)12.5 5.7 0.30 0.10 Gas (MMSCFD)9.1 2.4 0.19 0.02 Water (MBD)54.5 10.3 0.00 0.00 Injection: Water (MBD)57.6 20.6 0.00 0.00 Gas (MMSCFD)2.8 0.0 0.00 0.00 AVERAGE OF PRESSURES OBTAINED IN 2013 (psig) - December 2013 3,260 1,615 3,797 psi Well Status: Milne Point Unit Boundary Hydraulic Unit Boundary Producer Injector Abandoned Kuparuk Formation Pressure Map, Milne Point Unit, 2013 Note: All pressures were taken in 2013, corrected to the datum @ 7000’ TVDss, and are shown in red. 1 1 2 mi 0 Note: All pressures were taken in 2013, corrected to the datum @ 8750’ TVDss, and are shown in red. Where multiple pressures were recorded in a well, the one with longest shut-in period is used. Sag River Formation Pressure Map Milne Point Unit, 2013 5183 2256 3953 Milne Point Unit Boundary Milne Point Sag River PA Well Status: Producer online Injector shut in Producer shut in Section 2 Kuparuk River Oil Pool List of Exhibits Waterflood Pattern Map 2-A Total Reservoir Production Plot 2-B Total Reservoir Injection Plot 2-C Pertinent Data Summary 2-D Reservoir Voidage Balance 2-E Static Pressure Data 2-F Injection Rate & Pressure Data By Well 2-G Kuparuk River Oil Pool Waterflood Project Summary The Kuparuk River Oil Pool waterflood area is shown in Exhibit 2-A. The locations of producing and injecting wells are shown, as are the interpreted hydraulic units. These hydraulic units represent regions of the reservoir that are believed to be hydraulically isolated due to faulting and/or lithologic controls. There were 77 producing wells and 49 injection wells active through 2013. Exhibit 2-B shows a production plot for the Kuparuk River reservoir covering the entire project history through December 2013. The Kuparuk River Oil Pool oil production averaged 12.5 MSTBD for 2013 compared to 12.7 MSTBD in 2012. This represents an oil production decrease of 1.5 % in 2013. Water production averaged 54.4 MBWD in 2013 and 61.4 MBWD in 2012, a decrease of 11.4%. Gas production averaged 9.1 MMSCFD in 2013. Cumulative production since waterflood startup through the end of 2013 is 241.6 MMSTB of oil, 134.5 BSCF gas, and 316.1 MMSTB of water. Exhibit 2-C shows an injection plot for the Kuparuk River reservoir covering the entire project history through December 2013. Water and gas injection rates averaged 57.6 MBWD and 2.8 MMSCFD for 2013. Injection rates in 2012 averaged 58.3 MBWD and 2.7 MMSCFD. This represents a slight decrease in water injection of 1.2% and an increase in gas injection of 3.7%. Cumulative water injection since waterflood startup through the end of 2013 is 493.5 MMSTB and cumulative gas injection is 105.2 BSCF. Average water cut decreased slightly from 82.9% in 2012 to 81.3% in 2013. Average GOR increased slightly from 710 SCF/STB in 2012 to 724 SCF/STB in 2013. Exhibit 2-D presents a summary of the pertinent production information for the Kuparuk River Oil Pool waterflood. Exhibit 2-E shows a monthly breakdown of production and injection data for the report period. This data shows that the voidage replacement ratio averaged 0.81 RB/RB in 2013. The VRR in 2012 averaged 0.75 RB/RB. This represents an increase of 8.0%. The cumulative VRR for the reservoir is 0.89 RB/RB. Exhibit 2-F presents the reservoir pressure data taken during 2013 for the Kuparuk River wells. In 2013, 121 pressures were obtained in 74 wells, 48 active producers and 26 active injectors. Exhibit 2-G provides a 2013 monthly summary of individual well injection rate and injection pressure data for all of the Kuparuk River Oil Pool injectors. Milne Point Unit Boundary Hydraulic Unit Boundary Well Status: Producer online Injector online Producer shut in/suspended Abandoned Injector shut in 1 1 2 mi 0 Kuparuk Formation Hydraulic Unit Map, Milne Point Field, 2013 MPK-21 MPN-01B Exhibit 2-B BP ALASKA - Milne Point Unit Kuparuk Reservoir, Total Production 10 100 1000 10000 100000 1000000 1 50001 100001 150001 200001 250001 300001 350001 Gas Prod (MMSCF, MSCF/DAY) Oil Prod (MSTB, STB/DAY) Water Prod (MSTB, STB/DAY) Oil Prod Cum KUP Oil Prod Rate KUP Water Prod Cum KUP Water Prod Rate KUP Gas Prod Cum KUP Gas Prod Rate KUP 0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 0 10 20 30 40 50 60 70 80 90 100 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 GOR/1000Water Cut % / # Producers OnLineWater Cut % KUP_Producers Online Gas/Oil Ratio KUP 2013 Ex 2-4 B&C production_injection.xls 1/21/2014 Exhibit 2-C BP ALASKA - Milne Point Unit Kuparuk Reservoir, Injection 100 1000 10000 100000 1000000 10000000 10 100 1000 10000 100000 1000000 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 Gas Injection (MMSCF, MSCF/DAY) Solvent Injection (MMSCF, MSCF/DAY) Water Injection (MSTB, STB/DAY) Water Inj Cum KUP Water Inj Rate KUP Gas Inj Cum KUP Gas Inj Rate KUP Solvent Inj Cum KUP Solvent Inj Rate KUP 0 5 10 15 20 25 30 35 40 45 50 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# of Injectors OnLineWater Injectors OnLine Gas Injectors OnLine MI Injectors OnLine 2013 Ex 2-4 B&C production_injection.xls 1/21/2014 Exhibit 2-D Exhibit 2-D Milne Point Unit - Kuparuk River Oil Pool Milne Point Unit - Kuparuk River Oil Pool SUMMARY OF PERTINENT DATA SUMMARY OF PERTINENT DATA 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)241,648 Gas (MMSCF)134,491 Water (MSTB)316,131 FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB)493,482 Injection Gas (MMSCF)105,224 Lean Gas (MMSCF)96,802 Solvent (MMSCF)8,422 AVERAGE OF PRESSURES OBTAINED IN 2013 @ 7,000' TVD ss December, 2013 Pressure (psig)3,260 WELL COUNT (Wells in Operation)* Production Wells 78 WAG Injection 36 Water Only Injection 11 Gas Only Injection 2 Notes: * Reflects ONLY operable wells. As of December 31, 2013 Exhibit 2-E Milne Point Unit Kuparuk River Oil Pool 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 12/31/2012 (stb/day)(stb/day)(mscf/day)(rbbl/day)(stb/day)(mscf/day)(rbbl/day)Ratio (rbbl/day) 1/31/2013 12,816 63,521 9433 84,564 67697 1949 70,387 0.83 -14,177 2/28/2013 13,354 53,826 8615 74,524 67902 1106 69,871 0.94 -4,653 3/31/2013 12,990 46,697 8870 67,166 67591 1811 70,161 1.04 2,994 4/30/2013 13,206 45,396 8765 65,958 68051 1761 70,585 1.07 4,627 5/31/2013 13,188 48,110 9071 68,958 68549 2477 71,705 1.04 2,747 6/30/2013 13,337 51,353 9245 72,539 56677 3888 60,867 0.84 -11,671 7/31/2013 12,363 52,698 9076 72,848 48842 3952 52,970 0.73 -19,878 8/31/2013 11,502 55,236 9110 74,648 27686 4177 31,690 0.42 -42,958 9/30/2013 12,748 60,717 8704 81,028 51840 3067 55,252 0.68 -25,775 10/31/2013 12,102 62,590 9180 82,734 51645 3155 55,130 0.67 -27,603 11/30/2013 11,466 56,188 9498 75,914 56356 3026 59,801 0.79 -16,113 12/31/2013 11,229 57,413 9291 76,758 58119 2656 61,273 0.80 -15,485 Average: 2013 12,525 54,479 9,072 74,803 57,580 2,752 60,808 0.81 -13,995 Cumulative:mstb mstb mmscf mrb mstb mmscf mrb mrb 31-Dec-13 241,648 316,131 134,491 662,410 493,482 105,224 591,284 0.89 -71,126 January - December 2013 RESERVOIR VOIDAGE BALANCE Page 1 Exhibit 2-F Static Pressure Data Kuparuk River Oil Pool 4. Field and Pool: Kuparuk River Pool 6. Oil Gravity: API - 23 8. Well Name and Number: 9. API Number 50-XXX-XXXXX-XX-XX 10. Oil (O) or Gas (G) 11. AOGCC Pool Code 12. Final Test Date 13. Shut-In Time, Hours 14. Press. Surv. Type (see instructions for codes) 15. B.H. Temp. 16. Depth Tool TVDss 17. Final Pressure at Tool Depth 18. Datum TVDss (input) 19. Pressure Gradient, psi/ft. 20. Pressure at Datum (cal) Comments Zone MPB-05A 50-500-29207-72-01 INJ 525100 9/26/2013 352 SBHP 132 7,000 4,678 7000 0.668 4,678 Grad = 0.39 psi/ft B+C MPB-13 50-500-29213-48-00 PROD 525100 6/9/2013 994,424 SBHP 172 7,000 2,869 7000 0.400 2,869 Grad = 0.43 psi/ft C MPB-19 50-500-29214-51-00 PROD 525100 7/29/2013 - SBHP 172 7,000 3,276 7000 0.370 3,276 Grad = 0.39 psi/ft C MPB-20 50-500-29215-24-00 INJ 525100 7/22/2013 311 SBHP 126 6,926 3,346 6700 0.145 3,379 Grad = 0.44 psi/ft TVD/SS=SS B+C MPC-04 50-500-29208-01-00 PROD 525100 8/14/2013 139 SBHP 176 7,000 2,417 7000 0.244 2,417 Grad = 0.36 psi/ft TVD/SS=TVD C MPC-09 50-500-29212-99-00 PROD 525100 12/20/2013 47,171 SBHP 168 6,911 3,323 7000 0.332 3,353 Grad = 0.3319 psi/ft A2+A3+B+C MPC-14 50-500-29213-44-00 PROD 525100 3/20/2013 1,471 SBHP 169 6,688 3,260 7000 0.370 3,376 Grad = 0.37 psi/ft A2+A3+B+C MPC-14 50-500-29213-44-00 PROD 525100 4/3/2013 1,815 SBHP 168 6,688 3,255 7000 0.370 3,371 Grad = 0.37 psi/ft A2+A3+B+C MPC-24A 50-500-29230-20-01 PROD 525100 5/17/2013 96 PP 143 5,768 1,912 7000 0.431 2,443 Gauge readings converted to datum using grad = 0.43 psi/ft A1+A2+A3 MPC-25A 50-500-29226-38-01 INJ 525100 8/25/2013 591 SBHP 152 7,000 5,742 7000 0.444 5,742 Grad = 0.419 psi/ft A2+A3+B+C MPC-39 50-500-29228-49-00 INJ 525100 1/18/2013 960 SBHP 150 6,900 4,872 7000 0.557 4,928 Grad = 0.44 psi/ft A2+A3+B+C MPC-40 50-500-29228-71-00 PROD 525100 7/24/2013 233 SBHP 171 7,000 2,482 7000 0.500 2,482 Grad = 0.40 psi/ft A3+B+C MPC-42 50-500-29231-96-00 INJ 525100 8/26/2013 663 SBHP 151 7,000 5,507 7000 0.426 5,507 Grad = 0.4311 psi/ft A2+A3+B+C MPE-07 50-500-29221-55-00 INJ 525100 7/24/2013 295 SBHP 124 7,000 3,770 7000 0.539 3,552 Grad = 0.44 psi/ft B+C MPE-08 50-500-29221-56-00 PROD 525100 6/11/2013 21,216 PP 6,689 2,844 7000 0.427 2,977 B+C MPE-10 50-500-29225-21-00 PROD 525100 2/14/2013 2,114 SBHP 167 6,617 2,936 7000 0.428 3,100 Grad = 0.43 psi/ft C MPE-11 50-500-29225-41-00 PROD 525100 4/20/2013 2,293 SBHP 170 6,650 2,956 7000 0.447 3,113 Grad = 0.44 psi/ft C MPE-11 50-500-29225-41-00 PROD 525100 5/22/2013 3,063 SBHP 170 6,650 3,082 7000 0.429 3,232 Grad = 0.43 psi/ft USED TVD DEPTH.C MPE-23 50-500-29225-70-00 INJ 525100 7/23/2013 336 SBHP 133 7,000 3,443 7000 0.492 3,448 Grad = 0.43 psi/ft B+C MPF-01 50-500-29225-52-00 PROD 525100 8/5/2013 96 PP 171 6,751 3,843 7000 0.430 3,950 PP reading converted to datum A1+A2+A3 MPF-05 50-500-29227-62-00 PROD 525100 8/6/2013 144 PP 181 6,769 2,013 7000 0.424 2,111 PP reading converted to datum A1+A2+A3 MPF-06 50-500-29226-39-00 PROD 525100 8/6/2013 96 PP 175 6,883 2,652 7000 0.428 2,702 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-09 50-500-29227-73-00 PROD 525100 8/5/2013 96 PP 168 6,861 2,253 7000 0.432 2,313 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-14 50-500-29226-36-00 PROD 525100 8/5/2013 72 PP 178 6,856 2,416 7000 0.431 2,478 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-18 50-500-29226-81-00 PROD 525100 8/6/2013 120 PP 175 7,011 2,726 7000 0.445 2,721 PP reading converted to datum A1+A2+A3 MPF-22 50-500-29226-32-00 PROD 525100 8/6/2013 120 PP 169 6,638 3,156 7000 0.431 3,312 PP reading converted to datum A1+A2+A3 MPF-25 50-500-29225-46-00 PROD 525100 3/17/2013 230 SBHP 186 6,980 2,934 7000 0.443 2,943 Grad = 0.45 psi/ft A1+A2+A3 MPF-25 50-500-29225-46-00 PROD 525100 8/6/2013 96 PP 187 7,026 2,962 7000 0.429 2,951 PP reading converted to datum A1+A2+A3 MPF-26 50-500-29227-67-00 INJ 525100 7/8/2013 309 SBHP 118 7,000 4,571 7000 2.813 4,572 Grad = 0.43 psi/ft A1+A2+A3 MPF-29 50-500-29226-88-00 PROD 525100 8/5/2013 72 PP 184 7,064 1,489 7000 0.436 1,461 PP reading converted to datum A1+A2+A3+B MPF-30 50-500-29226-23-00 INJ 525100 1/12/2013 205 SBHP 122 7,000 5,601 7000 0.769 5,601 Grad = 0.44 psi/ft A1+A2+A3 MPF-30 50-500-29226-23-00 INJ 525100 2/19/2013 1,144 SBHP 132 6,750 4,687 7000 0.436 4,796 Grad = 0.432 psi/ft A1+A2+A3 MPF-30 50-500-29226-23-00 INJ 525100 8/27/2013 1,802 SBHP 136 6,750 4,242 7000 0.432 4,350 Grad = 0.43 psi/ft A1+A2+A3 MPF-30 50-500-29226-23-00 INJ 525100 10/20/2013 466 SBHP 138 7,000 3,880 7000 0.000 3,880 Grad = 0.43 psi/ft A1+A2+A3 MPF-37 50-500-29225-48-00 PROD 525100 8/5/2013 96 PP 179 7,131 1,781 7000 0.427 1,725 PP reading converted to datum A1+A2+A3+C MPF-45 50-500-29225-56-00 PROD 525100 8/6/2013 96 PP 177 6,956 2,104 7000 0.364 2,120 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-46 50-500-29224-50-00 INJ 525100 3/17/2013 768 SBHP 117 7,000 4,211 7000 0.769 4,211 Grad = 0.43 psi/ft A1+A2+A3 MPF-46 50-500-29224-50-00 INJ 525100 4/16/2013 1,487 SBHP 121 7,000 3,981 7000 0.769 3,981 Grad = 0.43 psi/ft A1+A2+A3 MPF-46 50-500-29224-50-00 INJ 525100 8/27/2013 4,675 SBHP 126 7,000 3,552 7000 0.507 3,552 Grad = 0.44 psi/ft A1+A2+A3 MPF-50 50-500-29227-56-00 PROD 525100 8/7/2013 240 PP 184 7,064 1,186 7000 0.188 1,174 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-50 50-500-29227-56-00 PROD 525100 10/22/2013 863 SBHP 189 6,977 1,308 7000 0.349 1,316 Grad = 0.36 psi/ft A1+A2+A3 1. Operator: BPXA 2. Address: 900 E. Benson Blvd Anchorage, Alaska 99508-4254 7. Gas Gravity: Air = 1.05. Datum Reference: 7000' SS3. Unit or Lease Name: Milne Point STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT Exhibit 2-F Static Pressure Data Kuparuk River Oil Pool 8. Well Name and Number: 9. API Number 50-XXX-XXXXX-XX-XX 10. Oil (O) or Gas (G) 11. AOGCC Pool Code 12. Final Test Date 13. Shut-In Time, Hours 14. Press. Surv. Type (see instructions for codes) 15. B.H. Temp. 16. Depth Tool TVDss 17. Final Pressure at Tool Depth 18. Datum TVDss (input) 19. Pressure Gradient, psi/ft. 20. Pressure at Datum (cal) Comments Zone MPF-53 50-500-29225-78-00 525100 8/6/2013 186 SBHP 176 6,500 2,400 7000 0.446 2,623 Grad = 0.44 A1+A2+A3+C MPF-53 50-500-29225-78-00 525100 10/11/2013 185 SBHP 176 6,785 2,501 7000 0.433 2,594 Grad = 0.43 psi/ft A1+A2+A3+C MPF-53 50-500-29225-78-00 525100 10/19/2013 373 SBHP 175 6,785 2,628 7000 0.429 2,720 Grad = 0.43 psi/ft A1+A2+A3+C MPF-54 50-500-29227-26-00 PROD 525100 8/6/2013 96 PP 187 7,098 2,933 7000 0.428 2,891 PP reading converted to datum A2 MPF-57A 50-500-29227-47-01 PROD 525100 2/20/2013 24,730 SBHP 126 5,446 3,755 7000 0.401 4,378 Grad = 0.399 psi/ft A3 MPF-57A 50-500-29227-47-01 PROD 525100 4/1/2013 25,698 SBHP 115 5,117 3,553 7000 0.401 4,308 Grad = 0.40 psi/ft A3 MPF-57A 50-500-29227-47-01 PROD 525100 12/4/2013 1,287 PP 158 6,304 3,545 7000 0.425 3,841 A3 MPF-62 50-500-29226-09-00 INJ 525100 7/9/2013 300 SBHP 127 7,000 3,479 7000 0.357 3,479 Grad = 0.43 psi/ft A1+A2+A3+C MPF-65 50-500-29227-52-00 PROD 525100 8/6/2013 96 PP 191 7,323 1,558 7000 0.430 1,419 PP reading converted to datum A1+A2+A3 MPF-65 50-500-29227-52-00 PROD 525100 12/5/2013 226 PP 186 7,323 1,810 7000 0.405 1,679 A1+A2+A3 MPF-66A 50-500-29226-97-01 PROD 525100 8/6/2013 96 PP 189 7,255 1,647 7000 0.431 1,537 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-69 50-500-29225-86-00 PROD 525100 2/12/2013 2,832 PP 6,997 3,504 7000 0.322 3,505 A1+A2+A3+B MPF-69 50-500-29225-86-00 PROD 525100 8/7/2013 6,144 PP 182 6,997 3,708 7000 0.322 3,709 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3+B MPF-69 50-500-29225-86-00 PROD 525100 12/4/2013 9,883 PP 176 6,997 3,671 7000 0.322 3,672 A1+A2+A3+B MPF-70 50-500-29226-03-00 525100 1/17/2013 325 SBHP 122 6,734 4,620 7000 0.421 4,732 Grad = 0.44 psi/ft A1+A2+A3 MPF-70 50-500-29226-03-00 525100 3/1/2013 1,351 SBHP 132 6,734 4,128 7000 0.429 4,242 Grad = 0.44 psi/ft A1+A2+A3 MPF-70 50-500-29226-03-00 525100 8/28/2013 5,671 SBHP 141 6,750 3,514 7000 0.436 3,623 A1+A2+A3 MPF-70 50-500-29226-03-00 525100 8/28/2013 - SITP 141 6,750 3,507 8800 0.208 3,080 Grad = 0.44 psi/ft A1+A2+A3 MPF-70 50-500-29226-03-00 525100 10/24/2013 7,053 SBHP 144 6,750 3,385 7000 0.438 3,494 Grad = 0.4379 psi/ft A1+A2+A3 MPF-74 50-500-29226-82-00 INJ 525100 5/30/2013 744 PFO 155 7,238 3,753 7000 0.433 3,650 PFO readings converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-74 50-500-29226-82-00 INJ 525100 11/27/2013 5,078 SBHP 154 7,000 3,066 7000 0.333 3,066 Grad = 0.4337 psi/ft A1+A2+A3 MPF-78 50-500-29225-99-00 PROD 525100 8/6/2013 96 PP 194 7,168 3,225 7000 0.440 3,151 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-78 50-500-29225-99-00 PROD 525100 10/16/2013 171 SBHP 189 7,114 2,997 7000 0.447 2,946 Grad = 0.4486 psi/ft A1+A2+A3+B+C MPF-78 50-500-29225-99-00 PROD 525100 11/1/2013 516 SBHP 189 6,999 3,222 7000 0.431 3,222 Grad = 0.43 psi/ft A1+A2+A3+B+C MPF-78 50-500-29225-99-00 PROD 525100 11/29/2013 2,000 SBHP 184 7,000 3,348 7000 0.478 3,350 Grad = 0.4649 psi/ft A1+A2+A3+B+C MPF-81 50-500-29229-59-00 PROD 525100 8/6/2013 216 PP 176 6,491 1,981 7000 0.430 2,200 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-82A 50-500-29229-71-01 INJ 525100 8/12/2013 305 SBHP 122 6,500 4,684 7000 0.434 4,901 Grad = 0.43 psi/ft A2+A3 MPF-83 50-500-29229-63-00 INJ 525100 5/30/2013 24,936 SBHP 141 6,425 3,781 7000 0.588 4,119 Grad = 0.44 psi/ft A2+A3 MPF-84B 50-500-29229-31-02 INJ 525100 7/8/2013 315 SBHP 112 6,750 3,427 7000 0.423 3,533 Grad = 0.43 psi/ft A1+A2+A3 MPF-85 50-500-29229-36-00 INJ 525100 8/13/2013 312 SBHP 100 7,000 4,985 7000 0.588 4,985 Grad = 0.42 psi/ft TVD/SS=TVD A1 MPF-86 50-500-29230-18-00 PROD 525100 2/12/2013 3,408 PP 6,732 3,386 7000 0.440 3,504 A2 MPF-86 50-500-29230-18-00 PROD 525100 8/7/2013 7,440 PP 165 6,732 3,340 7000 0.428 3,455 PP reading converted to datum using grad = 0.44 psi/ft A2 MPF-87A 50-500-29231-84-01 PROD 525100 8/6/2013 96 PP 182 7,018 3,048 7000 0.440 3,040 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-90 50-500-29230-51-00 INJ 525100 5/29/2013 79,014 SBHP 83 4,241 2,582 7000 0.419 3,737 Grad = 0.44 psi/ft A1 MPF-91 50-500-29232-71-00 INJ 525100 8/14/2013 290 SBHP 127 7,000 3,506 7000 0.333 3,506 Grad = 0.43 psi/ft A1+A2+A3 MPF-93 50-500-29232-66-00 PROD 525100 8/7/2013 1,704 PP 137 5,745 2,680 7000 0.430 3,220 PP reading converted to datum A1+A2+A3 MPF-93 50-500-29232-66-00 PROD 525100 10/12/2013 4,948 SBHP 143 5,717 2,836 7000 0.436 3,395 Grad = 0.4355 psi/ft A1+A2+A3 MPF-94 50-500-29230-40-00 PROD 525100 2/12/2013 1,104 PP 7,321 3,490 7000 0.439 3,349 A1+A2+A3 MPF-94 50-500-29230-40-00 PROD 525100 2/18/2013 1,325 SBHP 171 6,795 3,300 7000 0.421 3,387 Grad = 0.421 psi/ft A1+A2+A3 MPF-94 50-500-29230-40-00 PROD 525100 8/6/2013 96 PP 185 7,301 2,888 7000 0.429 2,759 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPF-96 50-500-29234-06-00 PROD 525100 4/30/2013 1,579 SBHP 135 5,465 1,942 7000 0.399 2,555 Grad = 0.40 psi/ft A1+A2+A3 MPF-96 50-500-29234-06-00 PROD 525100 5/1/2013 1,625 SBHP 135 5,465 1,942 7000 0.405 2,564 Grad = 0.4051 psi/ft A1+A2+A3 MPF-96 50-500-29234-06-00 PROD 525100 8/6/2013 96 PP 150 5,481 1,624 7000 0.410 2,247 PP reading converted to datum using grad = 0.44 psi/ft A1+A2+A3 MPH-06 50-500-29225-80-00 INJ 525100 9/14/2013 339 SBHP 134 6,396 2,905 7000 0.455 3,180 Grad = 0.45 psi/ft B+C MPJ-10 50-500-29225-00-00 PROD 525100 5/16/2013 169 SBHP 174 6,651 3,525 7000 0.430 3,675 Grad = 0.43 psi/ft TVD/SS A2+A3+B MPJ-10 50-500-29225-00-00 PROD 525100 5/19/2013 260 SBHP 174 6,651 3,562 7000 0.428 3,712 Grad = 0.43 psi/ft TVD/SS=TVD A2+A3+B MPK-05 50-500-29226-70-00 PROD 525100 2/11/2013 12,768 PP 170 6,760 2,365 7000 0.433 2,469 B+C Exhibit 2-F Static Pressure Data Kuparuk River Oil Pool 8. Well Name and Number: 9. API Number 50-XXX-XXXXX-XX-XX 10. Oil (O) or Gas (G) 11. AOGCC Pool Code 12. Final Test Date 13. Shut-In Time, Hours 14. Press. Surv. Type (see instructions for codes) 15. B.H. Temp. 16. Depth Tool TVDss 17. Final Pressure at Tool Depth 18. Datum TVDss (input) 19. Pressure Gradient, psi/ft. 20. Pressure at Datum (cal) Comments Zone MPK-05 50-500-29226-70-00 PROD 525100 12/6/2013 19,920 SBHP 163 6,710 2,496 7000 0.364 2,602 Grad = 0.3639 psi/ft B+C MPK-13 50-500-29226-55-00 PROD 525100 2/13/2013 18,912 PP 161 6,777 2,319 7000 0.435 2,416 C MPK-21A 50-500-29227-18-01 INJ 525100 6/2/2013 40,076 SBHP 165 7,000 2,812 7000 0.402 2,812 Grad = 0.44 psi/ft B+C MPK-22 50-500-29232-49-00 INJ 525100 6/3/2013 40,083 SBHP 165 6,950 2,698 7000 0.417 2,719 Grad = 0.42 psi/ft C MPK-30 50-500-29227-11-00 PROD 525100 2/11/2013 9,912 PP 169 6,863 2,880 7000 0.438 2,940 B+C MPK-30 50-500-29227-11-00 PROD 525100 12/15/2013 17,273 SBHP 160 6,823 2,896 7000 0.371 2,962 USED TVD DEPTH Grad = 0.371 psi/ft B+C MPK-37 50-500-29226-74-00 PROD 525100 2/13/2013 31,704 PP 175 6,854 2,751 7000 0.431 2,814 C MPK-38 50-500-29226-49-00 PROD 525100 2/13/2013 34,512 PP 169 6,898 2,040 7000 0.441 2,085 B+C MPK-43A 50-500-29227-38-01 INJ 525100 6/4/2013 41,780 SBHP 150 7,000 2,104 7000 0.286 2,104 Grad = 0.32 psi/ft C MPL-02A 50-500-29219-98-01 PROD 525100 8/7/2013 3,672 PP 170 6,740 1,964 7000 0.431 2,076 PP reading converted to datum using grad = 0.44 psi/ft A2+A3 MPL-04 50-500-29220-29-00 PROD 525100 6/6/2013 620 SBHP 182 6,965 4,230 7000 0.046 4,228 Grad = 0.38 psi/ft A1+A2+A3+B+C MPL-04 50-500-29220-29-00 PROD 525100 6/8/2013 658 SBHP 182 6,965 4,261 7000 0.636 4,283 Grad = 0.38 psi/ft A1+A2+A3+B+C MPL-04 50-500-29220-29-00 PROD 525100 11/1/2013 4,147 SBHP 179 6,965 4,593 7000 0.371 4,606 Grad = 0.37 psi/ft A1+A2+A3+B+C MPL-09 50-500-29220-75-00 INJ 525100 1/1/2013 1,728 SBHP 130 7,000 4,563 7000 0.571 4,563 Grad = 0.4316 psi/ft A1+A2+A3+B+C MPL-09 50-500-29220-75-00 INJ 525100 8/17/2013 504 SBHP 6,998 3,480 7000 0.497 3,481 Pressure reading post injector flowback to reduce BHP in preperation for CTD sidetrack A1+A2+A3+B+C MPL-09 50-500-29220-75-00 INJ 525100 10/23/2013 2,146 SBHP 139 7,000 3,449 7000 0.493 3,449 Grad = 0.43 psi/ft A1+A2+A3+B+C MPL-09 50-500-29220-75-00 INJ 525100 11/12/2013 2,624 SBHP 137 7,000 3,433 7000 0.490 3,433 Grad = 0.44 psi/ft A1+A2+A3+B+C MPL-13 50-500-29223-35-00 PROD 525100 9/5/2013 866 SBHP 177 6,750 1,831 7000 0.380 1,926 Grad = 0.38 psi/ft A1+A2+A3+B+C MPL-13 50-500-29223-35-00 PROD 525100 10/31/2013 2,186 SBHP 174 6,750 2,528 7000 0.380 2,623 Grad = 0.38 psi/ft A1+A2+A3+B+C MPL-13 50-500-29223-35-00 PROD 525100 11/28/2013 2,855 SBHP 173 6,750 2,802 7000 0.376 2,896 Grad = 0.3759 psi/ft A1+A2+A3+B+C MPL-14 50-500-29224-79-00 PROD 525100 2/17/2013 183 SBHP 191 6,750 1,872 7000 0.644 2,033 Grad = 0.44 A1+A2+A3+B+C MPL-16A 50-500-29225-66-01 INJ 525100 6/17/2013 264 SBHP 122 7,000 3,469 7000 0.444 3,469 Grad = 0.4321 psi/ft A1+A2+A3+B+C MPL-17 50-500-29225-39-00 PROD 525100 6/5/2013 115,008 SBHP 152 6,475 3,269 7000 0.362 3,459 Grad = 0.38 psi/ft B MPL-20 50-500-29227-90-00 PROD 525100 4/11/2013 148 SBHP 140 4,858 4,908 7000 0.537 3,757 Grad = 0.470 psi/ft based on Test Numbers 1 and 2 A2+A3 MPL-21 50-500-29226-29-00 INJ 525100 6/10/2013 128,415 SBHP 109 5,002 3,373 7000 0.320 4,012 Grad = 0.32 psi/ft A MPL-25 50-500-29226-21-00 PROD 525100 5/18/2013 168 PP 7,137 3,763 7000 0.430 3,704 PP - Pump readings converted to BHP. grad = 0.44 psi/ft A1+A2+A3+B MPL-25 50-500-29226-21-00 PROD 525100 6/6/2013 26 SBHP 200 7,081 3,547 7000 0.483 3,508 Grad = 0.48 psi/ft A1+A2+A3+B MPL-25 50-500-29226-21-00 PROD 525100 11/24/2013 4,121 SBHP 184 7,081 3,956 7000 0.363 3,927 Grad = 0.3625 psi/ft A1+A2+A3+B MPL-25 50-500-29226-21-00 PROD 525100 12/5/2013 4,385 SBHP 183 7,081 3,929 7000 0.370 3,899 Grad = 0.3698 psi/ft A1+A2+A3+B MPL-33 50-500-29227-74-00 INJ 525100 6/15/2013 264 SBHP 110 7,000 4,796 7000 0.500 4,796 Grad = 0.43 psi/ft A1+A2+A3+C MPL-43 50-500-29231-90-00 PROD 525100 8/7/2013 840 PP 172 6,565 2,057 7000 0.430 2,244 PP reading converted to datum using grad = 0.44 psi/ft A+B+C MPL-43 50-500-29231-90-00 PROD 525100 11/28/2013 2,508 SBHP 168 6,481 2,192 7000 0.369 2,383 Grad = 0.3687 psi/ft A1+A2+A3+B+C MPL-43 50-500-29231-90-00 PROD 525100 12/8/2013 2,742 SBHP 168 6,481 2,189 7000 0.362 2,377 Grad = 0.3616 psi/ft A1+A2+A3+B+C Average 3,260 FL Fluid Level PBU Pressure Build Up PFO Pressure Fall Off PP Pump Pressure SBHP Shut-In Bottom Hole Pressure Signature Printed Name Title Gerrit Verbeek Reservoir Engineer 3/28/2014Date 21. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) MPB-05A 1/1/2013 2,552 26 H2O 22,972 884 MPB-05A 2/1/2013 0 H2O 0 MPB-05A 3/1/2013 2,488.80 23 H2O 27,352 1,189 MPB-05A 4/1/2013 2,533.70 26 H2O 20,716 797 MPB-05A 5/1/2013 2,586.80 31 H2O 29,399 948 MPB-05A 6/1/2013 2,571.00 30 H2O 25,999 867 MPB-05A 7/1/2013 2,551.30 31 H2O 27,544 888.52 MPB-05A 8/1/2013 2,584.40 31 H2O 33,911 1,094 MPB-05A 9/1/2013 2,450.60 16 H2O 15,512 970 MPB-05A 10/1/2013 2,549.70 31 H2O 42,136 1,359 MPB-05A 11/1/2013 2,637.10 30 H2O 38,817 1,294 MPB-05A 12/1/2013 2,104 31 H2O 53,684 1,732 MPB-08 1/1/2013 0 H2O 0 MPB-08 2/1/2013 0 H2O 0 MPB-08 3/1/2013 0 H2O 0 MPB-08 4/1/2013 0 H2O 0 MPB-08 5/1/2013 0 H2O 0 MPB-08 6/1/2013 0 H2O 0 MPB-08 7/1/2013 0 H2O 0 MPB-08 8/1/2013 0 H2O 0 MPB-08 9/1/2013 0 H2O 0 MPB-08 10/1/2013 0 H2O 0 MPB-08 11/1/2013 0 H2O 0 MPB-08 12/1/2013 0 H2O 0 MPB-11 1/1/2013 0 H2O 0 MPB-11 2/1/2013 0 H2O 0 MPB-11 3/1/2013 0 H2O 0 MPB-11 4/1/2013 0 H2O 0 MPB-11 5/1/2013 0 H2O 0 MPB-11 6/1/2013 0 H2O 0 MPB-11 7/1/2013 0 H2O 0 MPB-11 8/1/2013 0 H2O 0 MPB-11 9/1/2013 0 H2O 0 MPB-11 10/1/2013 0 H2O 0 MPB-11 11/1/2013 0 H2O 0 MPB-11 12/1/2013 0 H2O 0 MPB-12 1/1/2013 0 H2O 0 MPB-12 2/1/2013 0 H2O 0 MPB-12 3/1/2013 0 H2O 0 MPB-12 4/1/2013 0 H2O 0 MPB-12 5/1/2013 0 H2O 0 MPB-12 6/1/2013 0 H2O 0 MPB-12 7/1/2013 0 H2O 0 MPB-12 8/1/2013 0 H2O 0 MPB-12 9/1/2013 0 H2O 0 MPB-12 10/1/2013 0 H2O 0 MPB-12 11/1/2013 0 H2O 0 MPB-12 12/1/2013 0 H2O 0 Injection Rate and Pressure Data Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPB-14 1/1/2013 0 H2O 0 MPB-14 2/1/2013 0 H2O 0 MPB-14 3/1/2013 0 H2O 0 MPB-14 4/1/2013 0 H2O 0 MPB-14 5/1/2013 0 H2O 0 MPB-14 6/1/2013 0 H2O 0 MPB-14 7/1/2013 0 H2O 0 MPB-14 8/1/2013 0 H2O 0 MPB-14 9/1/2013 0 H2O 0 MPB-14 10/1/2013 0 H2O 0 MPB-14 11/1/2013 0 H2O 0 MPB-14 12/1/2013 0 H2O 0 MPB-17 1/1/2013 0 H2O 0 MPB-17 2/1/2013 0 H2O 0 MPB-17 3/1/2013 0 H2O 0 MPB-17 4/1/2013 0 H2O 0 MPB-17 5/1/2013 0 H2O 0 MPB-17 6/1/2013 0 H2O 0 MPB-17 7/1/2013 0 H2O 0 MPB-17 8/1/2013 0 H2O 0 MPB-17 9/1/2013 0 H2O 0 MPB-17 10/1/2013 0 H2O 0 MPB-17 11/1/2013 0 H2O 0 MPB-17 12/1/2013 0 H2O 0 MPB-18 1/1/2013 1,699.90 31 H2O 27,681 893 MPB-18 2/1/2013 1,767.30 28 H2O 25,133 898 MPB-18 3/1/2013 1,850.00 31 H2O 25,999 839 MPB-18 4/1/2013 1,895.40 30 H2O 24,290 810 MPB-18 5/1/2013 1,898.50 31 H2O 24,125 778 MPB-18 6/1/2013 1,908.60 30 H2O 23,140 771 MPB-18 7/1/2013 1,907.50 31 H2O 23,781 767.13 MPB-18 8/1/2013 1,828 31 H2O 22,445 724.03 MPB-18 9/1/2013 1,942.30 30 H2O 25,362 845.4 MPB-18 10/1/2013 1,979.90 31 H2O 28,236 910.84 MPB-18 11/1/2013 1,916.30 30 H2O 21,920 731 MPB-18 12/1/2013 1,926 31 H2O 24,264 783 MPB-20 1/1/2013 2460.1 31 H2O 83,058 2,679 MPB-20 2/1/2013 2,623 28 H2O 80,381 2,871 MPB-20 3/1/2013 2,687 31 H2O 92,301 2,977 MPB-20 4/1/2013 2,621 30 H2O 90,544 3,018 MPB-20 5/1/2013 2,570 31 H2O 96,282 3,106 MPB-20 6/1/2013 2,553 30 H2O 93,287 3,110 MPB-20 7/1/2013 2,188 19 H2O 50,364 2,651 MPB-20 8/1/2013 2,294 31 H2O 79,736 2,572 MPB-20 9/1/2013 2,505 30 H2O 86,419 2,881 MPB-20 10/1/2013 2536.7 31 H2O 96591 3115.84 MPB-20 11/1/2013 2409.9 30 H2O 89407 2980.23 MPB-20 12/1/2013 2,336.20 31 H2O 89,961 2901.97 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPB-25 1/1/2013 0 H2O 0 MPB-25 2/1/2013 0 H2O 0 MPB-25 3/1/2013 0 H2O 0 MPB-25 4/1/2013 0 H2O 0 MPB-25 5/1/2013 0 H2O 0 MPB-25 6/1/2013 0 H2O 0 MPB-25 7/1/2013 0 H2O 0 MPB-25 8/1/2013 0 H2O 0 MPB-25 9/1/2013 0 H2O 0 MPB-25 10/1/2013 0 H2O 0 MPB-25 11/1/2013 0 H2O 0 MPB-25 12/1/2013 0 H2O 0 MPC-02 1/1/2013 2,674 31 H2O 55,528 1791.23 MPC-02 2/1/2013 2,868.30 15 H2O 25,717 1714.47 MPC-02 3/1/2013 0 H2O 0 MPC-02 4/1/2013 2,490.00 16 H2O 21,401 1,338 MPC-02 5/1/2013 2,552.40 31 H2O 48,272 1,557 MPC-02 6/1/2013 2,451.80 30 H2O 46,827 1,561 MPC-02 7/1/2013 2,272.20 31 H2O 45,157 1,457 MPC-02 8/1/2013 2,120.50 25 H2O 32,194 1,288 MPC-02 9/1/2013 2,103.30 30 H2O 36,533 1,218 MPC-02 10/1/2013 2,172.50 31 H2O 46,063 1,486 MPC-02 11/1/2013 2,202.50 30 H2O 47,334 1577.8 MPC-02 12/1/2013 2,137.30 31 H2O 45,463 1,467 MPC-06 1/1/2013 1,859.40 30 H2O 42,710 1,424 MPC-06 2/1/2013 1,928.60 28 H2O 43,905 1,568 MPC-06 3/1/2013 1,868.80 31 H2O 47,020 1,517 MPC-06 4/1/2013 1,857 30 H2O 45,867 1,529 MPC-06 5/1/2013 1,833 31 H2O 48,299 1,558 MPC-06 6/1/2013 1,807.40 30 H2O 45,811 1527.03 MPC-06 7/1/2013 1,705 31 H2O 44,618 1,439 MPC-06 8/1/2013 1,776 31 H2O 60,899 1,964 MPC-06 9/1/2013 1,939 30 H2O 71,513 2,384 MPC-06 10/1/2013 1,940 31 H2O 71,822 2,317 MPC-06 11/1/2013 1972.2 30 H2O 76589 2552.97 MPC-06 12/1/2013 1,989.40 31 H2O 81,975 2644.35 MPC-08 1/1/2013 0 GAS 0 MPC-08 2/1/2013 0 GAS 0 MPC-08 3/1/2013 0 GAS 0 MPC-08 4/1/2013 0 GAS 0 MPC-08 5/1/2013 0 GAS 0 MPC-08 6/1/2013 0 GAS 0 MPC-08 7/1/2013 0 GAS 0 MPC-08 8/1/2013 0 GAS 0 MPC-08 9/1/2013 0 GAS 0 MPC-08 10/1/2013 0 GAS 0 MPC-08 11/1/2013 0 GAS 0 MPC-08 12/1/2013 0 GAS 0 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPC-10 1/1/2013 3,181.10 31 H2O 87708 2829.29 MPC-10 2/1/2013 3295.3 28 H2O 79867 2852.39 MPC-10 3/1/2013 3,349 31 H2O 90,588 2922.19 MPC-10 4/1/2013 3384.6 30 H2O 85965 2865.5 MPC-10 5/1/2013 3404.3 31 H2O 83322 2687.81 MPC-10 6/1/2013 3384.2 29 H2O 73280 2526.9 MPC-10 7/1/2013 3,210 31 H2O 69,986 2,258 MPC-10 8/1/2013 3,160 26 H2O 55,921 2,151 MPC-10 9/1/2013 3,228 30 H2O 59,532 1,984 MPC-10 10/1/2013 3,221 31 H2O 59,371 1,915 MPC-10 11/1/2013 3,250 30 H2O 58,912 1,964 MPC-10 12/1/2013 3,275 31 H2O 62,040 2,001 MPC-11 1/1/2013 0 H2O 0 MPC-11 2/1/2013 0 H2O 0 MPC-11 3/1/2013 0 H2O 0 MPC-11 4/1/2013 0 H2O 0 MPC-11 5/1/2013 0 H2O 0 MPC-11 6/1/2013 0 H2O 0 MPC-11 7/1/2013 0 H2O 0 MPC-11 8/1/2013 0 H2O 0 MPC-11 9/1/2013 0 H2O 0 MPC-11 10/1/2013 0 H2O 0 MPC-11 11/1/2013 0 H2O 0 MPC-11 12/1/2013 0 H2O 0 MPC-12A 1/1/2013 0 GAS 0 MPC-12A 2/1/2013 0 GAS 0 MPC-12A 3/1/2013 0 GAS 0 MPC-12A 4/1/2013 0 GAS 0 MPC-12A 5/1/2013 0 GAS 0 MPC-12A 6/1/2013 0 GAS 0 MPC-12A 7/1/2013 0 GAS 0 MPC-12A 8/1/2013 0 GAS 0 MPC-12A 9/1/2013 0 GAS 0 MPC-12A 10/1/2013 0 GAS 0 MPC-12A 11/1/2013 0 GAS 0 MPC-12A 12/1/2013 0 GAS 0 MPC-15 1/1/2013 0 H2O 0 MPC-15 2/1/2013 0 H2O 0 MPC-15 3/1/2013 0 H2O 0 MPC-15 4/1/2013 1,642 15 H2O 10,312 687 MPC-15 5/1/2013 1,943 31 H2O 24,651 795 MPC-15 6/1/2013 1,980 30 H2O 21,604 720.13 MPC-15 7/1/2013 1,927 31 H2O 19,696 635.35 MPC-15 8/1/2013 1,911 26 H2O 17,779 683.81 MPC-15 9/1/2013 2,067 30 H2O 23,205 773.5 MPC-15 10/1/2013 2073.1 31 H2O 23431 755.84 MPC-15 11/1/2013 2090.5 30 H2O 21641 721.37 MPC-15 12/1/2013 2204 31 H2O 32707 1055.06 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPC-17 1/1/2013 0 GAS 0 MPC-17 2/1/2013 0 GAS 0 MPC-17 3/1/2013 0 GAS 0 MPC-17 4/1/2013 0 GAS 0 MPC-17 5/1/2013 0 GAS 0 MPC-17 6/1/2013 0 GAS 0 MPC-17 7/1/2013 0 GAS 0 MPC-17 8/1/2013 0 GAS 0 MPC-17 9/1/2013 0 GAS 0 MPC-17 10/1/2013 0 GAS 0 MPC-17 11/1/2013 0 GAS 0 MPC-17 12/1/2013 0 GAS 0 MPC-19 1/1/2013 1,483.10 31 H2O 47,203 1522.68 MPC-19 2/1/2013 1230.1 28 H2O 28003 1000.11 MPC-19 3/1/2013 1239.5 31 H2O 29854 963.03 MPC-19 4/1/2013 1,283 30 H2O 30,673 1022.43 MPC-19 5/1/2013 1321.4 31 H2O 34840 1123.87 MPC-19 6/1/2013 1307 30 H2O 32907 1096.9 MPC-19 7/1/2013 1255.1 31 H2O 32728 1055.74 MPC-19 8/1/2013 1,090 30 H2O 27,019 900.63 MPC-19 9/1/2013 1,337 30 H2O 30,939 1031.3 MPC-19 10/1/2013 1,237 31 H2O 30,027 968.61 MPC-19 11/1/2013 1,164 30 H2O 28,409 947 MPC-19 12/1/2013 1,199 31 H2O 32,063 1,034 MPC-25A 1/1/2013 3,017 31 H2O 44,061 1421.32 MPC-25A 2/1/2013 3,076 28 H2O 38,889 1388.89 MPC-25A 3/1/2013 3,166 31 H2O 48,374 1,560 MPC-25A 4/1/2013 3,197.60 30 H2O 45,174 1505.8 MPC-25A 5/1/2013 3,246.50 31 H2O 48,653 1569.45 MPC-25A 6/1/2013 3,254.10 29 H2O 41,461 1429.69 MPC-25A 7/1/2013 3,084.80 31 H2O 40,401 1303.26 MPC-25A 8/1/2013 0 H2O 0 MPC-25A 9/1/2013 0 H2O 0 MPC-25A 10/1/2013 0 H2O 0 MPC-25A 11/1/2013 0 H2O 0 MPC-25A 12/1/2013 0 H2O 0 MPC-28A 1/1/2013 2,221.30 31 H2O 55,138 1,779 MPC-28A 2/1/2013 2,278 28 H2O 51,548 1,841 MPC-28A 3/1/2013 2,293.20 31 H2O 56,239 1,814 MPC-28A 4/1/2013 2,333.70 30 H2O 55,651 1855.03 MPC-28A 5/1/2013 2,358.00 31 H2O 57,947 1869.26 MPC-28A 6/1/2013 2,336.80 30 H2O 52,410 1,747 MPC-28A 7/1/2013 2,243.50 31 H2O 53,864 1,738 MPC-28A 8/1/2013 2,116.30 31 H2O 46,360 1,495 MPC-28A 9/1/2013 2,131.30 30 H2O 28,235 941 MPC-28A 10/1/2013 2,039.00 31 H2O 28,707 926 MPC-28A 11/1/2013 2,064.40 30 H2O 31,658 1,055 MPC-28A 12/1/2013 2,088.20 31 H2O 39,153 1,263 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPC-36 1/1/2013 902.00 1 H2O 540 540 MPC-36 2/1/2013 2,720.10 28 H2O 42,839 1,530 MPC-36 3/1/2013 2,844.70 31 H2O 46,061 1,486 MPC-36 4/1/2013 2,894.90 30 H2O 46,518 1,551 MPC-36 5/1/2013 2,935.00 31 H2O 47,540 1533.55 MPC-36 6/1/2013 2,943.50 29 H2O 44,140 1,522 MPC-36 7/1/2013 2,772.90 31 H2O 42,290 1364.19 MPC-36 8/1/2013 2,831 26 H2O 38,060 1463.85 MPC-36 9/1/2013 2,947.40 30 H2O 47,111 1,570 MPC-36 10/1/2013 2,983.30 31 H2O 47,300 1,526 MPC-36 11/1/2013 3,013.80 30 H2O 46,054 1,535 MPC-36 12/1/2013 3,034 31 H2O 49,867 1,609 MPC-39 1/1/2013 903.00 1 H2O 343 343 MPC-39 2/1/2013 2,585.00 28 H2O 20,737 741 MPC-39 3/1/2013 2,697.80 31 H2O 23,660 763.23 MPC-39 4/1/2013 2,785.30 30 H2O 24,731 824.37 MPC-39 5/1/2013 2812.1 31 H2O 24289 783.52 MPC-39 6/1/2013 2,859.20 29 H2O 23577 813 MPC-39 7/1/2013 2,728.00 31 H2O 24,039 775.45 MPC-39 8/1/2013 2,753.10 26 H2O 19,757 759.88 MPC-39 9/1/2013 2,857.50 30 H2O 23,633 787.77 MPC-39 10/1/2013 2,884.30 31 H2O 23,891 770.68 MPC-39 11/1/2013 2,912.30 30 H2O 21,982 732.73 MPC-39 12/1/2013 2,959.20 31 H2O 25,288 815.74 MPC-42 1/1/2013 2,787.40 31 H2O 44,372 1431.35 MPC-42 2/1/2013 2,894.20 28 H2O 43,746 1562.36 MPC-42 3/1/2013 2,923.40 31 H2O 47,131 1520.35 MPC-42 4/1/2013 2,938.80 30 H2O 44,355 1478.5 MPC-42 5/1/2013 2,970.70 31 H2O 46,209 1490.61 MPC-42 6/1/2013 2,991.40 29 H2O 44,353 1,529 MPC-42 7/1/2013 2,986.20 29 H2O 43,236 1,491 MPC-42 8/1/2013 0 H2O 0 MPC-42 9/1/2013 0 H2O 0 MPC-42 10/1/2013 2,276 21 H2O 19,085 909 MPC-42 11/1/2013 2,438 30 H2O 29,863 995 MPC-42 12/1/2013 2,528 31 H2O 30551 985.52 MPCFP-2 1/1/2013 0 H2O 0 MPCFP-2 2/1/2013 0 H2O 0 MPCFP-2 3/1/2013 0 H2O 0 MPCFP-2 4/1/2013 0 H2O 0 MPCFP-2 5/1/2013 0 H2O 0 MPCFP-2 6/1/2013 0 H2O 0 MPCFP-2 7/1/2013 0 H2O 0 MPCFP-2 8/1/2013 0 H2O 0 MPCFP-2 9/1/2013 0 H2O 0 MPCFP-2 10/1/2013 0 H2O 0 MPCFP-2 11/1/2013 0 H2O 0 MPCFP-2 12/1/2013 0 H2O 0 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPE-02 1/1/2013 0.1 31 GAS 60421 1949.06 MPE-02 2/1/2013 1109.3 21 GAS 8137 387.48 MPE-02 3/1/2013 3012 1 GAS 245 245 MPE-02 4/1/2013 0 GAS 0 MPE-02 5/1/2013 3252.7 3 GAS 2992 997.33 MPE-02 6/1/2013 0 GAS 0 MPE-02 7/1/2013 0 GAS 0 MPE-02 8/1/2013 3157.9 4 GAS 2,240 560 MPE-02 9/1/2013 0 GAS 0 MPE-02 10/1/2013 0 GAS 0 MPE-02 11/1/2013 0 GAS 0 MPE-02 12/1/2013 0 GAS 0 MPE-03 1/1/2013 0 GAS 0 MPE-03 2/1/2013 3,048.90 14 GAS 22,823 1,630 MPE-03 3/1/2013 3,101.70 31 GAS 55,885 1,803 MPE-03 4/1/2013 3128.2 30 GAS 52,842 1,761 MPE-03 5/1/2013 3173 30 GAS 73,794 2,460 MPE-03 6/1/2013 3238.3 30 GAS 116640 3888 MPE-03 7/1/2013 3185.6 31 GAS 122527 3952.48 MPE-03 8/1/2013 3197.4 31 GAS 127234 4104.32 MPE-03 9/1/2013 3258.3 30 GAS 92023 3067.43 MPE-03 10/1/2013 3,261.80 31 GAS 97,813 3155.26 MPE-03 11/1/2013 3,244.40 30 GAS 90,775 3025.83 MPE-03 12/1/2013 3,236.20 31 GAS 82,329 2655.77 MPE-05 1/1/2013 1,974.80 31 H2O 32,923 1062.03 MPE-05 2/1/2013 2,039.60 28 H2O 30,401 1085.75 MPE-05 3/1/2013 2,079.60 31 H2O 35,213 1135.9 MPE-05 4/1/2013 2,112.30 18 H2O 19,277 1070.94 MPE-05 5/1/2013 0 H2O 0 MPE-05 6/1/2013 1,943.70 21 H2O 22,650 1078.57 MPE-05 7/1/2013 1897.4 31 H2O 31534 1017.23 MPE-05 8/1/2013 1880.1 31 H2O 36934 1191.42 MPE-05 9/1/2013 2016.7 30 H2O 31932 1064.4 MPE-05 10/1/2013 2,077.30 31 H2O 45,165 1456.94 MPE-05 11/1/2013 2,031.30 30 H2O 30,354 1011.8 MPE-05 12/1/2013 2,034.50 31 H2O 29,747 959.58 MPE-07 1/1/2013 2,110.00 31 H2O 73,747 2378.94 MPE-07 2/1/2013 2,236 28 H2O 67,718 2,419 MPE-07 3/1/2013 2,302.00 31 H2O 75,048 2,421 MPE-07 4/1/2013 2,313.00 30 H2O 70,675 2,356 MPE-07 5/1/2013 2,312.50 31 H2O 73,934 2,385 MPE-07 6/1/2013 2,281.80 30 H2O 68,499 2,283 MPE-07 7/1/2013 1,841.00 19 H2O 36,543 1,923 MPE-07 8/1/2013 0 H2O 0 MPE-07 9/1/2013 0 H2O 0 MPE-07 10/1/2013 0 H2O 0 MPE-07 11/1/2013 0 H2O 0 MPE-07 12/1/2013 1,234 13 H2O 28,635 2,203 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPE-16 1/1/2013 0 H2O 0 MPE-16 2/1/2013 0 H2O 0 MPE-16 3/1/2013 0 H2O 0 MPE-16 4/1/2013 0 H2O 0 MPE-16 5/1/2013 0 H2O 0 MPE-16 6/1/2013 0 H2O 0 MPE-16 7/1/2013 0 H2O 0 MPE-16 8/1/2013 0 H2O 0 MPE-16 9/1/2013 0 H2O 0 MPE-16 10/1/2013 0 H2O 0 MPE-16 11/1/2013 0 H2O 0 MPE-16 12/1/2013 0 H2O 0 MPE-17 1/1/2013 2,010.20 31 H2O 64,495 2080.48 MPE-17 2/1/2013 2,073.70 28 H2O 66,616 2379.14 MPE-17 3/1/2013 2,090.80 31 H2O 77,967 2515.06 MPE-17 4/1/2013 2,082.00 30 H2O 75,188 2506.27 MPE-17 5/1/2013 2,055.40 31 H2O 77,310 2493.87 MPE-17 6/1/2013 2,011.90 30 H2O 71,508 2383.6 MPE-17 7/1/2013 1,881.90 31 H2O 67,945 2191.77 MPE-17 8/1/2013 1,876.90 31 H2O 38,421 1,239 MPE-17 9/1/2013 2,072.80 30 H2O 79,221 2,641 MPE-17 10/1/2013 2,072.50 31 H2O 78,783 2,541 MPE-17 11/1/2013 2,090 30 H2O 81,578 2,719 MPE-17 12/1/2013 1,779.00 2 H2O 4,583 2,292 MPE-23 1/1/2013 2,121.30 31 H2O 90,460 2,918 MPE-23 2/1/2013 2,209.60 28 H2O 84,585 3,021 MPE-23 3/1/2013 2,259.70 31 H2O 94,243 3,040 MPE-23 4/1/2013 2,240.60 30 H2O 89,019 2,967 MPE-23 5/1/2013 2,222.60 29 H2O 83,383 2,875 MPE-23 6/1/2013 2,192.70 30 H2O 89,933 2,998 MPE-23 7/1/2013 1,613.50 17 H2O 39,551 2,327 MPE-23 8/1/2013 0 H2O 0 MPE-23 9/1/2013 1,783.50 22 H2O 59,483 2703.77 MPE-23 10/1/2013 2,289.70 31 H2O 108,151 3488.74 MPE-23 11/1/2013 2,216 30 H2O 94,670 3155.67 MPE-23 12/1/2013 2,223.70 31 H2O 96,856 3124.39 MPE-26 1/1/2013 2,109.10 31 H2O 32,678 1054.13 MPE-26 2/1/2013 2132.1 28 H2O 31463 1123.68 MPE-26 3/1/2013 2,158.90 31 H2O 34,978 1128.32 MPE-26 4/1/2013 2,161.00 30 H2O 33,639 1,121 MPE-26 5/1/2013 2,156.60 31 H2O 35,187 1,135 MPE-26 6/1/2013 2,152.20 30 H2O 33,883 1,129 MPE-26 7/1/2013 2,001.70 31 H2O 33,027 1,065 MPE-26 8/1/2013 1,859.20 31 H2O 25,600 826 MPE-26 9/1/2013 1,968.20 30 H2O 27,800 927 MPE-26 10/1/2013 1,967.00 31 H2O 31,778 1,025 MPE-26 11/1/2013 2,021.40 30 H2O 32,546 1,085 MPE-26 12/1/2013 2,009.90 31 H2O 31,494 1,016 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPF-10 1/1/2013 1,462.50 31 H2O 36,041 1,163 MPF-10 2/1/2013 1,575.60 28 H2O 34,225 1,222 MPF-10 3/1/2013 1,662.20 31 H2O 39,043 1,259 MPF-10 4/1/2013 1,967 30 H2O 49,831 1,661 MPF-10 5/1/2013 2,126 31 H2O 51,825 1,672 MPF-10 6/1/2013 2,161 30 H2O 47,901 1,597 MPF-10 7/1/2013 2,046 31 H2O 42,629 1,375 MPF-10 8/1/2013 1709.4 9 H2O 15273 1697 MPF-10 9/1/2013 1992.9 30 H2O 42094 1403.13 MPF-10 10/1/2013 1897.4 31 H2O 36505 1177.58 MPF-10 11/1/2013 2203.8 30 H2O 48276 1609.2 MPF-10 12/1/2013 2241.8 31 H2O 46326 1494.39 MPF-13 1/1/2013 2444 31 H2O 44574 1437.87 MPF-13 2/1/2013 3007.8 28 H2O 54843 1958.68 MPF-13 3/1/2013 3255 21 H2O 38725 1844.05 MPF-13 4/1/2013 1952.6 7 H2O 7415 1059.29 MPF-13 5/1/2013 3000.3 31 H2O 66881 2157.45 MPF-13 6/1/2013 3345.8 30 H2O 61165 2038.83 MPF-13 7/1/2013 2897 31 H2O 44967 1450.55 MPF-13 8/1/2013 2035.4 8 H2O 10875 1359.38 MPF-13 9/1/2013 2153.4 30 H2O 30447 1014.9 MPF-13 10/1/2013 2094.5 31 H2O 31469 1015.13 MPF-13 11/1/2013 2163.6 30 H2O 33407 1113.57 MPF-13 12/1/2013 2115.1 31 H2O 34309 1106.74 MPF-17 1/1/2013 0 H2O 0 MPF-17 2/1/2013 0 H2O 0 MPF-17 3/1/2013 0 H2O 0 MPF-17 4/1/2013 0 H2O 0 MPF-17 5/1/2013 0 H2O 0 MPF-17 6/1/2013 0 H2O 0 MPF-17 7/1/2013 0 H2O 0 MPF-17 8/1/2013 0 H2O 0 MPF-17 9/1/2013 0 H2O 0 MPF-17 10/1/2013 0 H2O 0 MPF-17 11/1/2013 0 H2O 0 MPF-17 12/1/2013 0 H2O 0 MPF-26 1/1/2013 1,962.20 31 H2O 59,955 1934.03 MPF-26 2/1/2013 2,150.70 28 H2O 54,492 1946.14 MPF-26 3/1/2013 2,236.50 31 H2O 61,605 1987.26 MPF-26 4/1/2013 2,376 30 H2O 62,640 2,088 MPF-26 5/1/2013 2387.4 31 H2O 60696 1957.94 MPF-26 6/1/2013 2339.9 26 H2O 49809 1915.73 MPF-26 7/1/2013 820.3 3 H2O 3292 1097.33 MPF-26 8/1/2013 1233.6 9 H2O 18132 2014.67 MPF-26 9/1/2013 1890.1 30 H2O 64000 2133.33 MPF-26 10/1/2013 1600.9 31 H2O 38165 1231.13 MPF-26 11/1/2013 2111.4 30 H2O 67684 2256.13 MPF-26 12/1/2013 2229.4 31 H2O 63958 2063.16 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPF-30 1/1/2013 2529.7 3 H2O 4689 1563 MPF-30 2/1/2013 2230.2 9 H2O 21850 2427.78 MPF-30 3/1/2013 2768.6 31 H2O 68194 2199.81 MPF-30 4/1/2013 2,746.30 30 H2O 48,527 1617.57 MPF-30 5/1/2013 2,534 31 H2O 30,022 968.45 MPF-30 6/1/2013 2,112.30 12 H2O 8,314 692.83 MPF-30 7/1/2013 0 H2O 0 MPF-30 8/1/2013 0 H2O 0 MPF-30 9/1/2013 0 H2O 0 MPF-30 10/1/2013 0 H2O 0 MPF-30 11/1/2013 0 H2O 0 MPF-30 12/1/2013 0 H2O 0 MPF-41 1/1/2013 0 H2O 0 MPF-41 2/1/2013 0 H2O 0 MPF-41 3/1/2013 0 H2O 0 MPF-41 4/1/2013 0 H2O 0 MPF-41 5/1/2013 0 H2O 0 MPF-41 6/1/2013 0 H2O 0 MPF-41 7/1/2013 0 H2O 0 MPF-41 8/1/2013 0 H2O 0 MPF-41 9/1/2013 0 H2O 0 MPF-41 10/1/2013 0 H2O 0 MPF-41 11/1/2013 0 H2O 0 MPF-41 12/1/2013 0 H2O 0 MPF-42 1/1/2013 2,873.70 31 H2O 82,159 2,650 MPF-42 2/1/2013 3,042.50 28 H2O 78,522 2,804 MPF-42 3/1/2013 3,089.40 31 H2O 84,434 2,724 MPF-42 4/1/2013 3,131 30 H2O 80,786 2,693 MPF-42 5/1/2013 3072.6 31 H2O 76125 2455.65 MPF-42 6/1/2013 2960.3 30 H2O 72142 2404.73 MPF-42 7/1/2013 2741.3 31 H2O 58551 1888.74 MPF-42 8/1/2013 2224.8 8 H2O 15505 1938.13 MPF-42 9/1/2013 2510.3 30 H2O 67374 2245.8 MPF-42 10/1/2013 2510 31 H2O 59486 1918.9 MPF-42 11/1/2013 2796.9 30 H2O 77622 2587.4 MPF-42 12/1/2013 2876.6 31 H2O 80012 2581.03 MPF-46 1/1/2013 2101.5 31 H2O 61591 1986.81 MPF-46 2/1/2013 2223.2 13 H2O 25676 1975.08 MPF-46 3/1/2013 0 H2O 0 MPF-46 4/1/2013 0 H2O 0 MPF-46 5/1/2013 0 H2O 0 MPF-46 6/1/2013 0 H2O 0 MPF-46 7/1/2013 0 H2O 0 MPF-46 8/1/2013 0 H2O 0 MPF-46 9/1/2013 0 H2O 0 MPF-46 10/1/2013 0 H2O 0 MPF-46 11/1/2013 0 H2O 0 MPF-46 12/1/2013 0 H2O 0 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPF-49 1/1/2013 0 H2O 0 MPF-49 2/1/2013 0 H2O 0 MPF-49 3/1/2013 0 H2O 0 MPF-49 4/1/2013 0 H2O 0 MPF-49 5/1/2013 0 H2O 0 MPF-49 6/1/2013 0 H2O 0 MPF-49 7/1/2013 0 H2O 0 MPF-49 8/1/2013 0 H2O 0 MPF-49 9/1/2013 0 H2O 0 MPF-49 10/1/2013 0 H2O 0 MPF-49 11/1/2013 0 H2O 0 MPF-49 12/1/2013 0 H2O 0 MPF-62 1/1/2013 1,582.60 31 H2O 43,513 1,404 MPF-62 2/1/2013 1,289.80 28 H2O 34,846 1,245 MPF-62 3/1/2013 1,437.50 31 H2O 41,016 1,323 MPF-62 4/1/2013 1,791.00 30 H2O 45,067 1,502 MPF-62 5/1/2013 1,781.80 31 H2O 45,060 1,454 MPF-62 6/1/2013 1,731.00 26 H2O 36,180 1,392 MPF-62 7/1/2013 1,431.10 23 H2O 28,099 1,222 MPF-62 8/1/2013 1,266.70 9 H2O 12,236 1,360 MPF-62 9/1/2013 1,143.70 30 H2O 35,770 1,192 MPF-62 10/1/2013 754.00 31 H2O 26,565 857 MPF-62 11/1/2013 1,101.50 30 H2O 36,760 1,225 MPF-62 12/1/2013 2,043.70 31 H2O 57,337 1,850 MPF-70 1/1/2013 2,008.70 3 H2O 5,947 1,982 MPF-70 2/1/2013 0 H2O 0 MPF-70 3/1/2013 0 H2O 0 MPF-70 4/1/2013 0 H2O 0 MPF-70 5/1/2013 0 H2O 0 MPF-70 6/1/2013 0 H2O 0 MPF-70 7/1/2013 0 H2O 0 MPF-70 8/1/2013 0 H2O 0 MPF-70 9/1/2013 0 H2O 0 MPF-70 10/1/2013 0 H2O 0 MPF-70 11/1/2013 0 H2O 0 MPF-70 12/1/2013 0 H2O 0 MPF-74 1/1/2013 0 H2O 0 MPF-74 2/1/2013 0 H2O 0 MPF-74 3/1/2013 0 H2O 0 MPF-74 4/1/2013 1,700.30 8 H2O 14,514 1,814 MPF-74 5/1/2013 0 H2O 0 MPF-74 6/1/2013 0 H2O 0 MPF-74 7/1/2013 0 H2O 0 MPF-74 8/1/2013 0 H2O 0 MPF-74 9/1/2013 0 H2O 0 MPF-74 10/1/2013 0 H2O 0 MPF-74 11/1/2013 0 H2O 0 MPF-74 12/1/2013 0 H2O 0 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPF-82A 1/1/2013 3,445.80 31 H2O 18,609 600 MPF-82A 2/1/2013 3,455.80 28 H2O 17,128 612 MPF-82A 3/1/2013 3,455.10 31 H2O 19,145 618 MPF-82A 4/1/2013 3,454 30 H2O 17,833 594 MPF-82A 5/1/2013 3,449 31 H2O 18,243 588 MPF-82A 6/1/2013 3,394 30 H2O 16,309 544 MPF-82A 7/1/2013 3,257 31 H2O 13,012 420 MPF-82A 8/1/2013 0 H2O 0 MPF-82A 9/1/2013 3,126 26 H2O 19,822 762 MPF-82A 10/1/2013 3,361 31 H2O 22,425 723 MPF-82A 11/1/2013 3,445 30 H2O 21,020 701 MPF-82A 12/1/2013 3,444 31 H2O 20,490 661 MPF-83 1/1/2013 0 H2O 0 MPF-83 2/1/2013 0 H2O 0 MPF-83 3/1/2013 0 H2O 0 MPF-83 4/1/2013 0 H2O 0 MPF-83 5/1/2013 0 H2O 0 MPF-83 6/1/2013 0 H2O 0 MPF-83 7/1/2013 0 H2O 0 MPF-83 8/1/2013 0 H2O 0 MPF-83 9/1/2013 0 H2O 0 MPF-83 10/1/2013 0 H2O 0 MPF-83 11/1/2013 0 H2O 0 MPF-83 12/1/2013 0 H2O 0 MPF-84B 1/1/2013 1,617.60 31 H2O 78,810 2542.26 MPF-84B 2/1/2013 1,733.80 28 H2O 75,049 2680.32 MPF-84B 3/1/2013 1,755 31 H2O 82,336 2656 MPF-84B 4/1/2013 1,722 30 H2O 76,537 2551.23 MPF-84B 5/1/2013 1612.6 26 H2O 64611 2485.04 MPF-84B 6/1/2013 1435.3 24 H2O 45467 1894.46 MPF-84B 7/1/2013 0 H2O 0 MPF-84B 8/1/2013 0 H2O 0 MPF-84B 9/1/2013 1041.6 30 H2O 82687 2756.23 MPF-84B 10/1/2013 911 31 H2O 62914 2029.48 MPF-84B 11/1/2013 1557.3 30 H2O 103863 3462.1 MPF-84B 12/1/2013 1901.7 31 H2O 117441 3788.42 MPF-85 1/1/2013 3275.2 31 H2O 54270 1750.65 MPF-85 2/1/2013 3298.6 28 H2O 49377 1763.46 MPF-85 3/1/2013 3308.2 31 H2O 54975 1773.39 MPF-85 4/1/2013 3,363 30 H2O 54,929 1830.97 MPF-85 5/1/2013 3,366 31 H2O 56,405 1,820 MPF-85 6/1/2013 3,318.40 30 H2O 54,527 1,818 MPF-85 7/1/2013 3,126.30 31 H2O 50,649 1,634 MPF-85 8/1/2013 2,456.00 8 H2O 14,258 1,782 MPF-85 9/1/2013 2,803.20 30 H2O 50,447 1,682 MPF-85 10/1/2013 2,944.00 31 H2O 53,658 1730.9 MPF-85 11/1/2013 3,075.40 30 H2O 54,090 1,803 MPF-85 12/1/2013 3,186.00 31 H2O 59,292 1,913 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPF-88 1/1/2013 1,801.40 31 H2O 102,486 3,306 MPF-88 2/1/2013 1,849.70 28 H2O 96,485 3,446 MPF-88 3/1/2013 1,859.80 31 H2O 110,166 3,554 MPF-88 4/1/2013 1,887.60 30 H2O 108,390 3,613 MPF-88 5/1/2013 1,775.60 31 H2O 101,686 3,280 MPF-88 6/1/2013 1,164.60 30 H2O 57,437 1,915 MPF-88 7/1/2013 1,012.20 31 H2O 60,168 1,941 MPF-88 8/1/2013 541.60 9 H2O 12,565 1,396 MPF-88 9/1/2013 699.10 30 H2O 26,667 889 MPF-88 10/1/2013 491.30 4 H2O 3,227 807 MPF-88 11/1/2013 0 H2O 0 MPF-88 12/1/2013 0 H2O 0 MPF-89 1/1/2013 2,399.80 31 H2O 25,324 817 MPF-89 2/1/2013 2,503.40 12 H2O 11,247 937 MPF-89 3/1/2013 1,899 12 H2O 11,505 959 MPF-89 4/1/2013 2,830.30 30 H2O 50,137 1,671 MPF-89 5/1/2013 3,206.90 31 H2O 53,299 1,719 MPF-89 6/1/2013 3,171.70 6 H2O 9,055 1,509 MPF-89 7/1/2013 0 H2O 0 MPF-89 8/1/2013 0 H2O 0 MPF-89 9/1/2013 0 H2O 0 MPF-89 10/1/2013 0 H2O 0 MPF-89 11/1/2013 0 H2O 0 MPF-89 12/1/2013 0 H2O 0 MPF-90 1/1/2013 0 H2O 0 MPF-90 2/1/2013 0 H2O 0 MPF-90 3/1/2013 0 H2O 0 MPF-90 4/1/2013 0 H2O 0 MPF-90 5/1/2013 0 H2O 0 MPF-90 6/1/2013 0 H2O 0 MPF-90 7/1/2013 0 H2O 0 MPF-90 8/1/2013 0 H2O 0 MPF-90 9/1/2013 0 H2O 0 MPF-90 10/1/2013 0 H2O 0 MPF-90 11/1/2013 0 H2O 0 MPF-90 12/1/2013 0 H2O 0 MPF-91 1/1/2013 1,890 31 H2O 32,842 1059.42 MPF-91 2/1/2013 1,992 28 H2O 30,619 1093.54 MPF-91 3/1/2013 1,994 31 H2O 33,307 1074.42 MPF-91 4/1/2013 1,976.20 30 H2O 32,498 1083.27 MPF-91 5/1/2013 1,949.30 31 H2O 33,314 1074.65 MPF-91 6/1/2013 1,909.60 30 H2O 33,259 1108.63 MPF-91 7/1/2013 1,686.60 31 H2O 27,999 903.19 MPF-91 8/1/2013 79.00 1 H2O 56 56 MPF-91 9/1/2013 1,559.30 26 H2O 21,897 842.19 MPF-91 10/1/2013 1,647.50 31 H2O 28,327 913.77 MPF-91 11/1/2013 1,710.90 30 H2O 31,306 1043.53 MPF-91 12/1/2013 1,988.10 31 H2O 53,866 1737.61 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPF-92 1/1/2013 3,039.20 26 H2O 26,054 1002.08 MPF-92 2/1/2013 0 H2O 0 MPF-92 3/1/2013 1,553.70 3 H2O 2,442 814 MPF-92 4/1/2013 2597.4 30 H2O 28093 936.43 MPF-92 5/1/2013 3,131 31 H2O 55,718 1797.35 MPF-92 6/1/2013 3,226 30 H2O 42,573 1,419 MPF-92 7/1/2013 2,919.60 31 H2O 26,070 840.97 MPF-92 8/1/2013 2,423.10 8 H2O 7,298 912 MPF-92 9/1/2013 2,805.90 30 H2O 31,513 1,050 MPF-92 10/1/2013 2,986.80 31 H2O 37,719 1,217 MPF-92 11/1/2013 3,000.70 30 H2O 30,109 1003.63 MPF-92 12/1/2013 3,162.40 31 H2O 42,225 1362.1 MPF-95 1/1/2013 1,433.50 21 H2O 20,145 959 MPF-95 2/1/2013 0 H2O 0 MPF-95 3/1/2013 938.50 2 H2O 2,391 1195.5 MPF-95 4/1/2013 1,197 30 H2O 37,844 1,261 MPF-95 5/1/2013 1,452 31 H2O 50,416 1,626 MPF-95 6/1/2013 1,429 30 H2O 37,267 1,242 MPF-95 7/1/2013 1,178.90 31 H2O 27,166 876 MPF-95 8/1/2013 996.60 8 H2O 7,042 880.25 MPF-95 9/1/2013 1,193.50 30 H2O 39,888 1329.6 MPF-95 10/1/2013 1,306.80 10 H2O 14,297 1429.7 MPF-95 11/1/2013 0 H2O 0 MPF-95 12/1/2013 0 H2O 0 MPF-99 1/1/2013 3,433.20 31 H2O 29,582 954.26 MPF-99 2/1/2013 3,464.00 28 H2O 27,442 980.07 MPF-99 3/1/2013 3,466.30 31 H2O 30,528 984.77 MPF-99 4/1/2013 3,490 30 H2O 29,886 996 MPF-99 5/1/2013 3,490 31 H2O 30,680 990 MPF-99 6/1/2013 3,408 30 H2O 28,561 952 MPF-99 7/1/2013 3,212.60 31 H2O 26,658 859.94 MPF-99 8/1/2013 2,795.40 8 H2O 8,846 1105.75 MPF-99 9/1/2013 3,176.70 30 H2O 29,051 968.37 MPF-99 10/1/2013 3,282 31 H2O 29,527 952.48 MPF-99 11/1/2013 3,475.90 30 H2O 30,825 1027.5 MPF-99 12/1/2013 3,482 31 H2O 31,342 1011.03 MPH-06 1/1/2013 1,495.70 31 H2O 73,955 2385.65 MPH-06 2/1/2013 1,546.30 28 H2O 71,958 2569.93 MPH-06 3/1/2013 1,560.90 31 H2O 82,117 2,649 MPH-06 4/1/2013 1,535.40 30 H2O 78,061 2,602 MPH-06 5/1/2013 1,508.20 31 H2O 80,758 2605.1 MPH-06 6/1/2013 1,493.00 30 H2O 76,624 2554.13 MPH-06 7/1/2013 1,439.20 31 H2O 73,013 2355.26 MPH-06 8/1/2013 1,213.10 31 H2O 53,379 1721.9 MPH-06 9/1/2013 1,442 14 H2O 33,112 2365.14 MPH-06 10/1/2013 1,545 31 H2O 82,278 2654.13 MPH-06 11/1/2013 1,492 26 H2O 64,635 2485.96 MPH-06 12/1/2013 1,548 31 H2O 82,199 2651.58 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPJ-11 1/1/2013 2,398 31 H2O 44,023 1420.1 MPJ-11 2/1/2013 2,513 28 H2O 42,775 1527.68 MPJ-11 3/1/2013 2,553 31 H2O 48,500 1564.52 MPJ-11 4/1/2013 2,516.20 30 H2O 42,742 1424.73 MPJ-11 5/1/2013 2,483.40 31 H2O 43,381 1,399 MPJ-11 6/1/2013 2,412.00 30 H2O 36,324 1,211 MPJ-11 7/1/2013 2,321.00 31 H2O 35,393 1,142 MPJ-11 8/1/2013 2,277 31 H2O 37,340 1,205 MPJ-11 9/1/2013 2,417.10 30 H2O 39,775 1,326 MPJ-11 10/1/2013 2,346.90 31 H2O 41,451 1,337 MPJ-11 11/1/2013 2,482.30 30 H2O 43,311 1,444 MPJ-11 12/1/2013 2,379.90 31 H2O 34,386 1,109 MPJ-13 1/1/2013 2,216.60 31 H2O 68,286 2,203 MPJ-13 2/1/2013 2,319 28 H2O 61,214 2,186 MPJ-13 3/1/2013 2,336.50 31 H2O 65,097 2,100 MPJ-13 4/1/2013 2,279.80 25 H2O 47,319 1,893 MPJ-13 5/1/2013 0 H2O 0 MPJ-13 6/1/2013 1,926.40 6 H2O 9,347 1,558 MPJ-13 7/1/2013 2,116.20 31 H2O 56,720 1,830 MPJ-13 8/1/2013 2,074.10 31 H2O 45,895 1,480 MPJ-13 9/1/2013 2,056.40 30 H2O 37,225 1,241 MPJ-13 10/1/2013 2,077.30 31 H2O 45,218 1,459 MPJ-13 11/1/2013 2,112.20 30 H2O 43,716 1,457 MPJ-13 12/1/2013 1,979.30 31 H2O 32,983 1,064 MPJ-16 1/1/2013 0 H2O 0 MPJ-16 2/1/2013 0 H2O 0 MPJ-16 3/1/2013 0 H2O 0 MPJ-16 4/1/2013 0 H2O 0 MPJ-16 5/1/2013 0 H2O 0 MPJ-16 6/1/2013 0 H2O 0 MPJ-16 7/1/2013 0 H2O 0 MPJ-16 8/1/2013 0 H2O 0 MPJ-16 9/1/2013 0 H2O 0 MPJ-16 10/1/2013 0 H2O 0 MPJ-16 11/1/2013 0 H2O 0 MPJ-16 12/1/2013 0 H2O 0 MPK-18A 1/1/2013 0 H2O 0 MPK-18A 2/1/2013 0 H2O 0 MPK-18A 3/1/2013 0 H2O 0 MPK-18A 4/1/2013 0 H2O 0 MPK-18A 5/1/2013 0 H2O 0 MPK-18A 6/1/2013 0 H2O 0 MPK-18A 7/1/2013 0 H2O 0 MPK-18A 8/1/2013 0 H2O 0 MPK-18A 9/1/2013 0 H2O 0 MPK-18A 10/1/2013 0 H2O 0 MPK-18A 11/1/2013 0 H2O 0 MPK-18A 12/1/2013 0 H2O 0 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPK-21A 1/1/2013 0 H2O 0 MPK-21A 2/1/2013 0 H2O 0 MPK-21A 3/1/2013 0 H2O 0 MPK-21A 4/1/2013 0 H2O 0 MPK-21A 5/1/2013 0 H2O 0 MPK-21A 6/1/2013 0 H2O 0 MPK-21A 7/1/2013 0 H2O 0 MPK-21A 8/1/2013 0 H2O 0 MPK-21A 9/1/2013 0 H2O 0 MPK-21A 10/1/2013 0 H2O 0 MPK-21A 11/1/2013 835.9 21 H2O 33070 1574.76 MPK-21A 12/1/2013 1137.8 31 H2O 48087 1551.19 MPK-22 1/1/2013 0 H2O 0 MPK-22 2/1/2013 0 H2O 0 MPK-22 3/1/2013 0 H2O 0 MPK-22 4/1/2013 0 H2O 0 MPK-22 5/1/2013 0 H2O 0 MPK-22 6/1/2013 0 H2O 0 MPK-22 7/1/2013 0 H2O 0 MPK-22 8/1/2013 0 H2O 0 MPK-22 9/1/2013 0 H2O 0 MPK-22 10/1/2013 0 H2O 0 MPK-22 11/1/2013 0 H2O 0 MPK-22 12/1/2013 684.3 22 H2O 25351 1152.32 MPK-43A 1/1/2013 0 H2O 0 MPK-43A 2/1/2013 0 H2O 0 MPK-43A 3/1/2013 0 H2O 0 MPK-43A 4/1/2013 0 H2O 0 MPK-43A 5/1/2013 0 H2O 0 MPK-43A 6/1/2013 0 H2O 0 MPK-43A 7/1/2013 0 H2O 0 MPK-43A 8/1/2013 0 H2O 0 MPK-43A 9/1/2013 0 H2O 0 MPK-43A 10/1/2013 0 H2O 0 MPK-43A 11/1/2013 0 H2O 0 MPK-43A 12/1/2013 0 H2O 0 MPL-08 1/1/2013 3420.3 31 H2O 36931 1191.32 MPL-08 2/1/2013 3431.4 28 H2O 33369 1191.75 MPL-08 3/1/2013 3431.4 31 H2O 36884 1189.81 MPL-08 4/1/2013 3440.4 30 H2O 35476 1182.53 MPL-08 5/1/2013 3434.1 31 H2O 36066 1163.42 MPL-08 6/1/2013 3374.5 6 H2O 6747 1124.5 MPL-08 7/1/2013 0 H2O 0 MPL-08 8/1/2013 0 H2O 0 MPL-08 9/1/2013 0 H2O 0 MPL-08 10/1/2013 0 H2O 0 MPL-08 11/1/2013 0 H2O 0 MPL-08 12/1/2013 0 H2O 0 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPL-09 1/1/2013 0 H2O 0 MPL-09 2/1/2013 0 H2O 0 MPL-09 3/1/2013 0 H2O 0 MPL-09 4/1/2013 0 H2O 0 MPL-09 5/1/2013 0 H2O 0 MPL-09 6/1/2013 0 H2O 0 MPL-09 7/1/2013 0 H2O 0 MPL-09 8/1/2013 0 H2O 0 MPL-09 9/1/2013 0 H2O 0 MPL-09 10/1/2013 0 H2O 0 MPL-09 11/1/2013 0 H2O 0 MPL-09 12/1/2013 0 H2O 0 MPL-10 1/1/2013 0 H2O 0 MPL-10 2/1/2013 0 H2O 0 MPL-10 3/1/2013 0 H2O 0 MPL-10 4/1/2013 0 H2O 0 MPL-10 5/1/2013 0 H2O 0 MPL-10 6/1/2013 0 H2O 0 MPL-10 7/1/2013 0 H2O 0 MPL-10 8/1/2013 0 H2O 0 MPL-10 9/1/2013 0 H2O 0 MPL-10 10/1/2013 0 H2O 0 MPL-10 11/1/2013 0 H2O 0 MPL-10 12/1/2013 0 H2O 0 MPL-15 1/1/2013 2,748.80 31 H2O 67,229 2,169 MPL-15 2/1/2013 2,846.10 28 H2O 63,767 2,277 MPL-15 3/1/2013 2,754.20 27 H2O 52,320 1937.78 MPL-15 4/1/2013 1982.1 7 H2O 9472 1353.14 MPL-15 5/1/2013 2353.4 31 H2O 42744 1378.84 MPL-15 6/1/2013 2410.3 30 H2O 41705 1390.17 MPL-15 7/1/2013 2180.5 31 H2O 32569 1050.61 MPL-15 8/1/2013 1963.5 8 H2O 10991 1373.88 MPL-15 9/1/2013 2405.1 30 H2O 49778 1659.27 MPL-15 10/1/2013 2439.2 31 H2O 47117 1519.9 MPL-15 11/1/2013 2351.8 5 H2O 7200 1440 MPL-15 12/1/2013 1589.9 14 H2O 12932 923.71 MPL-16A 1/1/2013 1751.2 31 H2O 108391 3496.48 MPL-16A 2/1/2013 1904.8 28 H2O 102531 3661.82 MPL-16A 3/1/2013 1945.3 31 H2O 112613 3632.68 MPL-16A 4/1/2013 1,951.30 30 H2O 108,559 3618.63 MPL-16A 5/1/2013 1,896.10 31 H2O 105,941 3,417 MPL-16A 6/1/2013 1,282.70 8 H2O 19,245 2,406 MPL-16A 7/1/2013 1,223.20 31 H2O 78,413 2,529 MPL-16A 8/1/2013 1,042.60 8 H2O 22,466 2,808 MPL-16A 9/1/2013 1,353.80 30 H2O 86,383 2,879 MPL-16A 10/1/2013 1,083.40 30 H2O 62,026 2,068 MPL-16A 11/1/2013 1,683 30 H2O 108,574 3619.13 MPL-16A 12/1/2013 1,803.20 31 H2O 111,217 3,588 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPL-21 1/1/2013 0 GAS 0 MPL-21 2/1/2013 0 GAS 0 MPL-21 3/1/2013 0 GAS 0 MPL-21 4/1/2013 0 GAS 0 MPL-21 5/1/2013 0 GAS 0 MPL-21 6/1/2013 0 GAS 0 MPL-21 7/1/2013 0 GAS 0 MPL-21 8/1/2013 0 GAS 0 MPL-21 9/1/2013 0 GAS 0 MPL-21 10/1/2013 0 GAS 0 MPL-21 11/1/2013 0 GAS 0 MPL-21 12/1/2013 0 GAS 0 MPL-24 1/1/2013 3,293.50 31 H2O 37,790 1,219 MPL-24 2/1/2013 3,268.00 28 H2O 34,534 1,233 MPL-24 3/1/2013 3,266.10 31 H2O 39,024 1,259 MPL-24 4/1/2013 3,277 30 H2O 38,303 1,277 MPL-24 5/1/2013 3204.5 15 H2O 18500 1233.33 MPL-24 6/1/2013 0 H2O 0 MPL-24 7/1/2013 0 H2O 0 MPL-24 8/1/2013 0 H2O 0 MPL-24 9/1/2013 0 H2O 0 MPL-24 10/1/2013 0 H2O 0 MPL-24 11/1/2013 0 H2O 0 MPL-24 12/1/2013 0 H2O 0 MPL-32 1/1/2013 3387 31 H2O 41157 1327.65 MPL-32 2/1/2013 3395 28 H2O 36704 1310.86 MPL-32 3/1/2013 3395 31 H2O 40529 1307.39 MPL-32 4/1/2013 3,396.90 8 H2O 10,372 1296.5 MPL-32 5/1/2013 3,178.50 16 H2O 27,610 1,726 MPL-32 6/1/2013 3,398.10 30 H2O 44,683 1,489 MPL-32 7/1/2013 3,139.90 31 H2O 33,472 1,080 MPL-32 8/1/2013 2,837.60 8 H2O 9,623 1,203 MPL-32 9/1/2013 3,051.80 30 H2O 32,395 1,080 MPL-32 10/1/2013 3,055.90 31 H2O 35,189 1,135 MPL-32 11/1/2013 3,286.40 30 H2O 39,998 1,333 MPL-32 12/1/2013 3,303.80 31 H2O 37,930 1,224 MPL-33 1/1/2013 3,009.50 31 H2O 88,651 2,860 MPL-33 2/1/2013 3,139.20 28 H2O 81,041 2,894 MPL-33 3/1/2013 3,215.30 31 H2O 86,403 2,787 MPL-33 4/1/2013 3,328.50 30 H2O 92,295 3,077 MPL-33 5/1/2013 3,340 31 H2O 91,400 2,948 MPL-33 6/1/2013 3,251.80 4 H2O 10,408 2,602 MPL-33 7/1/2013 2,068.10 29 H2O 68,961 2,378 MPL-33 8/1/2013 2,046.90 8 H2O 21,435 2,679 MPL-33 9/1/2013 2,443.40 30 H2O 88,451 2,948 MPL-33 10/1/2013 2,179.80 31 H2O 62,885 2,029 MPL-33 11/1/2013 2,662.80 19 H2O 63,474 3,341 MPL-33 12/1/2013 2,528.20 14 H2O 51,676 3,691 Exhibit 2-G Milne Point Field Kuparuk River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPL-34 1/1/2013 0 H2O 0 MPL-34 2/1/2013 0 H2O 0 MPL-34 3/1/2013 0 H2O 0 MPL-34 4/1/2013 0 H2O 0 MPL-34 5/1/2013 0 H2O 0 MPL-34 6/1/2013 0 H2O 0 MPL-34 7/1/2013 0 H2O 0 MPL-34 8/1/2013 0 H2O 0 MPL-34 9/1/2013 0 H2O 0 MPL-34 10/1/2013 0 H2O 0 MPL-34 11/1/2013 0 H2O 0 MPL-34 12/1/2013 0 H2O 0 MPL-39 1/1/2013 0 H2O 0 MPL-39 2/1/2013 0 H2O 0 MPL-39 3/1/2013 0 H2O 0 MPL-39 4/1/2013 0 H2O 0 MPL-39 5/1/2013 0 H2O 0 MPL-39 6/1/2013 0 H2O 0 MPL-39 7/1/2013 0 H2O 0 MPL-39 8/1/2013 0 H2O 0 MPL-39 9/1/2013 0 H2O 0 MPL-39 10/1/2013 0 H2O 0 MPL-39 11/1/2013 0 H2O 0 MPL-39 12/1/2013 0 H2O 0 MPL-42 1/1/2013 0 GAS 0 MPL-42 2/1/2013 0 GAS 0 MPL-42 3/1/2013 0 GAS 0 MPL-42 4/1/2013 0 GAS 0 MPL-42 5/1/2013 0 GAS 0 MPL-42 6/1/2013 0 GAS 0 MPL-42 7/1/2013 0 GAS 0 MPL-42 8/1/2013 0 GAS 0 MPL-42 9/1/2013 0 GAS 0 MPL-42 10/1/2013 0 GAS 0 MPL-42 11/1/2013 0 GAS 0 MPL-42 12/1/2013 0 GAS 0 Section 3 Schrader Bluff Oil Pool List of Exhibits Waterflood Pattern Map 3-A Total Reservoir Production Plot 3-B Total Reservoir Injection Plot 3-C Pertinent Data Summary 3-D Reservoir Voidage Balance 3-E Static Pressure Data 3-F Injection Rate & Pressure Data By Well 3-G Daily Allocation Factors 3-H 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 39 producing wells and 39 injection wells active during 2013.1 Exhibit 3-B shows a production plot for the Schrader Bluff reservoir covering the entire project history through December 2013. The Schrader Bluff Oil Pool oil production averaged 5.7 MSTBD for 2013 compared to 4.5 MSTBD in 2012. This represents an oil production increase of 26.7% in 2013. Gas production remained flat from 2012 to 2013 at an average gas production of 2.4 MMSCFD. Water production averaged 10.3 MBWD in 2013 compared to 11.8 MBWD in 2012. Cumulative production since waterflood startup through the end of 2013 is 69.6 MMSTB of oil, 41.7 BSCF of gas, and 61.5 MMSTB of water. Exhibit 3-C shows an injection plot for the Schrader Bluff reservoir covering the entire project history through December 2013. The water injection rate averaged 20.6 MBWD for 2013 compared to 16.7 MBWD in 2012. This increase of water injection rate is consistent with an increase in total reservoir fluid offtake from 2012 to 2013. Cumulative water injection since waterflood startup through the end of 2013 is 149.6 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 2013. Cumulative gas injection through the end of 2013 remains as it was at year-end 2008: 220 MMSCF. As of December 2013 the cumulative under injection is 29.3 MMRB. In the supported waterflood patterns, under-injection is minimal. The average voidage replacement ratio, or VRR, for 2013 was 1.13, an increase compared to the 2012 VRR of 0.89. Water cut decreased from 72.5% in 2012 to 64.2% in 2013. GOR was down slightly from 526 SCF/STB in 2012 to 413 SCF/STB in 2013. Exhibit 3-D is a summary of the pertinent production information for the Schrader Bluff Oil Pool in 2013. 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. 1 Note that the count of 39 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 49 active injectors. Exhibit 3-E shows a monthly breakdown of production and injection data for the report period. Exhibit 3-F presents the reservoir pressure data for the Schrader Bluff wells taken during 2013. In 2013, 103 pressures were obtained in 51 Schrader Bluff wells, 17 injectors (dual string counted separately) and 34 producers. Exhibit 3-G provides a monthly summary of individual well injection rate and injection pressure data for all of the Schrader Bluff Oil Pool injectors. Exhibit 3-H provides daily oil, gas, and water allocation factors for the Milne Point facility for 2013. 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 2013 was 0.90. This is a slight increase from the 2012 average of 0.85. For 2013, the water allocation factor averaged 1.12, and the gas allocation factor was 1.14. The water allocation factor improved over the 2012 average of 1.44 and the gas allocation factor improved compared to 2012's average of 1.16. Exhibit 3-B BP ALASKA - Milne Point Unit Schrader Reservoir, Total Production 10.000 100.000 1000.000 10000.000 100000.000 10 10010 20010 30010 40010 50010 60010 70010 80010 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 Gas Production (MMSCF, MSCF/DAY) Oil Production (MSTB, STB/DAY) Water Production (MSTB, STB/DAY) Oil Prod Cum SCH Oil Prod Rate SCH Water Prod Cum SCH Water Prod Rate SCH Gas Prod Cum SCH Gas Prod Rate SCH 0.0 0.2 0.4 0.6 0.8 1.0 1.2 0 10 20 30 40 50 60 70 80 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 GOR/1000Water Cut/ # Producers OnLineWater Cut % SCH_Producers OnLine Gas/Oil Ratio SCH 2013 Ex 2-4 B&C production_injection.xls 1/21/2014 Exhibit 3-C BP ALASKA - Milne Point Unit Schrader Reservoir, Injection 1 100 10000 1000000 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13Water Injection (MSTB, STB/DAY)Gas Injection (MMSCF, MSCF/DAY) Water Inj Cum SCH Water Inj Rate SCH Gas Inj Cum SCH Gas Inj Rate SCH 0 5 10 15 20 25 30 35 40 45 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13# Injectors OnLine Water Injectors OnLine Gas Injectors OnLine 2013 Ex 2-4 B&C production_injection.xls 1/21/2014 Exhibit 3-D Exhibit 3-D Milne Point Unit - Schrader Bluff Oil Pool Milne Point Unit - Schrader Bluff Oil Pool SUMMARY OF PERTINENT DATA SUMMARY OF PERTINENT DATA 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)69,594 Gas (MMSCF)41,713 Water (MSTB)61,469 FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB)149,616 Injection Gas (MMSCF)220 AVERAGE OF PRESSURES OBTAINED IN 2013 @ 4,000' TVD ss December, 2013 Pressure (psig)1,615 WELL COUNT (Wells in Operation)* Production Wells 39 WAG Injection 0 Water Only Injection 39 Gas Only Injection 0 Notes: * Reflects ONLY operable wells As of December 31, 2013 Exhibit 3-E Milne Point Unit Schrader Bluff Oil Pool 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 41274 (stb/day) (stb/day) (mscf/day) (rbbl/day) (stb/day) (mscf/day) (rbbl/day) Ratio (rbbl/day) 1/31/2013 4014 6728 1913 12,816 17563 0 17,739 1.38 4,923 2/28/2013 4769 8887 2087 15,847 18322 0 18,505 1.17 2,658 3/31/2013 5437 8815 2403 16,772 21412 0 21,626 1.29 4,854 4/30/2013 5321 9036 2381 16,872 20103 0 20,304 1.20 3,432 5/31/2013 5905 10950 2425 19,326 20326 0 20,529 1.06 1,203 6/30/2013 7189 12220 3147 22,701 22603 0 22,829 1.01 128 7/31/2013 6279 10199 2956 19,663 21503 0 21,718 1.10 2,055 8/31/2013 5044 11255 2353 18,856 19240 0 19,432 1.03 577 9/30/2013 5643 10168 2833 18,951 21387 0 21,601 1.14 2,650 10/31/2013 6304 12019 2080 20,192 21463 0 21,678 1.07 1,485 11/30/2013 6091 10920 1826 18,531 22151 0 22,373 1.21 3,841 12/31/2013 6832 12225 1989 20,672 20678 0 20,885 1.01 212 Average: 2013 5,736 10,285 2,366 18,433 20,563 0 20,768 1.13 2,335 Cumulative: mstb mstb mmscf mrb mstb mmscf mrb mrb 31-Dec-13 70,496 61,605 42,016 180,726 149,616 220 151,445 0.84 -29,281 January - December 2013 RESERVOIR VOIDAGE BALANCE Page 1 Exhibit 3-F Static Pressure Data Schrader Bluff Pool 8. Well Name and Number: 9. API Number 50- XXX-XXXXX-XX-XX 10. Oil (O) or Gas (G) 11. AOGCC Pool Code 12. Final Test Date 13. Shut-In Time, Hours 14. Press. Surv. Type (see instructions for codes) 15. B.H. Temp. 16. Depth Tool TVDss 17. Final Pressure at Tool Depth 18. Datum TVDss (input) 19. Pressure Gradient, psi/ft.20. Pressure at Datum (cal) Comments Zone MPB-02 50-500-29206-62-00 INJ 525140 7/25/2013 360 SBHP 79 4,000 2,415 4,000 0.440 2,415 N MPB-27LS 50-500-29232-33-80 INJ 525140 7/17/2013 10,872 SBHP 74 4,000 1,833 4,000 0.440 1,833 OA MPE-12 50-500-29232-62-00 INJ 525140 7/10/2013 240 SBHP 84 4,000 2,548 4,000 0.390 2,548 NC+ND MPE-13BSS 50-500-29225-36-81 INJ 525140 8/7/2013 216 SBHP 82 3,688 2,138 4,000 0.470 2,285 NB MPE-15 50-500-29225-28-00 PROD 525140 12/31/2013 909 PP 4,075 1,541 4,000 0.440 1,508 NB+OA MPE-20A 50-500-29225-61-01 PROD 525140 2/8/2013 2,184 PP 4,167 1,537 4,000 0.440 1,463 NB+OA MPE-20A 50-500-29225-61-01 PROD 525140 7/28/2013 384 PP 4,167 1,477 4,000 0.440 1,403 NB+OA MPE-20A 50-500-29225-61-01 PROD 525140 8/13/2013 768 PP 4,167 1,518 4,000 0.440 1,444 NB+OA MPE-29 50-500-29230-04-00 INJ 525140 9/5/2013 1,056 SBHP 49 2,203 926 4,000 0.440 1,717 OA+OB MPG-02 50-500-29219-26-00 PROD 525140 1/3/2013 504 SBHP 102 3,660 1,149 4,000 0.440 1,297 NA+NB+NC MPG-02 50-500-29219-26-00 PROD 525140 3/29/2013 4,704 PP 3,700 1,152 4,000 0.440 1,284 NA+NB+NC MPG-09 50-500-29227-79-00 INJ 525140 5/12/2013 18,384 SBHP 74 3,776 2,088 4,000 0.450 2,187 OA MPG-10 50-500-29227-80-00 INJ 525140 8/9/2013 336 SBHP 83 3,900 2,329 4,000 0.380 2,367 NB+OA+OB MPG-13 50-500-29227-82-00 INJ 525140 9/10/2013 250 SBHP 77 3,838 2,685 4,000 0.430 2,755 NB+OA+OB MPG-14 50-500-29230-31-00 PROD 525140 1/25/2013 2,553 SBHP 82 3,826 1,352 4,000 0.390 1,420 N+OA+OB MPG-14 50-500-29230-31-00 PROD 525140 2/15/2013 3,072 PP 3,851 1,400 4,000 0.440 1,466 N+OA+OB MPG-15 50-500-29227-84-00 PROD 525140 1/6/2013 20,020 SBHP 56 2,809 1,309 4,000 0.390 1,774 NB+NC+OA+OB MPG-16 50-500-29231-89-00 PROD 525140 4/20/2013 3,480 SBHP 89 4,125 1,395 4,000 0.400 1,345 OA+OB MPG-16 50-500-29231-89-00 PROD 525140 4/26/2013 3,624 PP 4,151 1,379 4,000 0.440 1,312 OA+OB MPG-16 50-500-29231-89-00 PROD 525140 12/31/2013 1,268 PP 4,151 1,310 4,000 0.440 1,243 OA+OB MPG-18 50-500-29231-94-00 PROD 525140 1/10/2013 696 SBHP 86 3,988 1,395 4,000 0.380 1,399 OA MPG-18 50-500-29231-94-00 PROD 525140 3/8/2013 2,064 PP 4,021 1,455 4,000 0.440 1,446 OA MPG-18 50-500-29231-94-00 PROD 525140 9/30/2013 1,464 PP 3,863 1,583 4,000 0.440 1,643 OA+OB MPG-18 50-500-29231-94-00 PROD 525140 11/29/2013 2,934 PP 3,863 1,634 4,000 0.440 1,695 OA MPG-19 50-500-29232-28-00 INJ 525140 8/31/2013 6,144 SBHP 79 4,000 2,170 4,000 0.430 2,169 OB MPG-19 50-500-29232-28-00 INJ 525140 9/1/2013 6,173 SBHP 79 4,000 2,303 4,000 0.390 2,301 OA MPH-04 50-500-29220-64-00 PROD 525140 8/20/2013 37,333 SBHP 68 3,250 1,494 4,000 0.410 1,802 N+OA+OB MPH-07A 50-500-29225-97-01 PROD 525140 3/31/2013 16,848 PP 3,973 1,282 4,000 0.440 1,294 OA+OB MPH-07A 50-500-29225-97-01 PROD 525140 6/7/2013 18,504 SBHP 79 3,962 1,306 4,000 0.030 1,307 OA+OB MPH-07A 50-500-29225-97-01 PROD 525140 6/7/2013 18,480 PP 3,973 1,294 4,000 0.440 1,306 OA+OB MPH-07A 50-500-29225-97-01 PROD 525140 9/7/2013 144 PP 3,973 968 4,000 0.440 980 OA+OB MPH-08B 50-500-29228-08-02 PROD 525140 5/24/2013 240 SBHP 78 3,653 1,149 4,000 0.430 1,298 OA+OB MPH-13A 50-500-29228-18-01 PROD 525140 3/31/2013 11,784 PP 3,860 1,051 4,000 0.440 1,112 NB MPH-13A 50-500-29228-18-01 PROD 525140 6/30/2013 13,968 PP 3,860 1,063 4,000 0.440 1,124 MBE with MPG-09 NB NB MPH-13A 50-500-29228-18-01 PROD 525140 9/30/2013 16,176 PP 3,860 1,068 4,000 0.440 1,129 NB MPH-13A 50-500-29228-18-01 PROD 525140 12/31/2013 18,416 PP 3,860 1,073 4,000 0.440 1,134 NB MPH-16 50-500-29232-27-00 PROD 525140 3/31/2013 2,928 PP 3,863 1,267 4,000 0.440 1,327 OA+OB MPH-16 50-500-29232-27-00 PROD 525140 5/23/2013 4,200 PP 3,863 1,262 4,000 0.440 1,322 OA+OB MPH-16 50-500-29232-27-00 PROD 525140 11/28/2013 368 PP 3,863 1,095 4,000 0.440 1,155 OA+OB MPH-19 50-500-29233-71-00 PROD 525140 2/10/2013 25,191 SBHP 80 3,959 1,624 4,000 0.420 1,641 OA MPI-03 50-500-29220-67-00 PROD 525140 3/7/2013 1,127 SBHP 92 3,535 1,142 4,000 0.370 1,314 NA+NB+NC+NE+OA+OB MPI-04A 50-500-29220-68-01 PROD 525140 3/31/2013 9,480 PP 3,687 1,436 4,000 0.440 1,574 NA+NB+NC+OA+OB MPI-04A 50-500-29220-68-01 PROD 525140 6/30/2013 11,664 PP 3,687 1,441 4,000 0.440 1,579 MBE with MPH-15 OA NA+NB+NC+OA+OB MPI-04A 50-500-29220-68-01 PROD 525140 9/30/2013 13,872 PP 3,687 1,435 4,000 0.440 1,573 NA+NB+NC+OA+OB MPI-04A 50-500-29220-68-01 PROD 525140 12/31/2013 16,086 PP 3,687 1,429 4,000 0.440 1,567 NA+NB+NC+OA+OB MPI-07 50-500-29226-02-00 PROD 525140 1/25/2013 7,678 SBHP 77 3,444 1,429 4,000 0.130 1,501 NB+OA+OB MPI-07 50-500-29226-02-00 PROD 525140 5/19/2013 288 PP 3,465 1,253 4,000 0.440 1,488 NB+OA+OB MPI-07 50-500-29226-02-00 PROD 525140 6/14/2013 72 PP 3,465 1,167 4,000 0.440 1,402 NB+OA+OB MPI-08 50-500-29228-21-00 INJ 525140 5/23/2013 384 SBHP 3,784 2,160 4,000 0.440 2,255 NB MPI-08 50-500-29228-21-00 INJ 525140 5/23/2013 384 SBHP 3,885 2,359 4,000 0.440 2,410 OA MPI-11 50-500-29230-33-00 PROD 525140 3/31/2013 22,272 PP 3,484 1,712 4,000 0.440 1,939 OA+OB MPI-11 50-500-29230-33-00 PROD 525140 6/30/2013 24,456 PP 3,484 1,696 4,000 0.440 1,923 OA+OB MPI-11 50-500-29230-33-00 PROD 525140 9/30/2013 26,664 PP 3,484 1,682 4,000 0.440 1,909 OA+OB MPI-11 50-500-29230-33-00 PROD 525140 12/31/2013 28,893 PP 3,484 1,666 4,000 0.440 1,893 OA+OB MPI-12 50-500-29230-38-00 PROD 525140 8/8/2013 240 PP 3,535 1,021 4,000 0.440 1,226 OA+OB MPI-12 50-500-29230-38-00 PROD 525140 9/30/2013 1,488 PP 3,535 1,119 4,000 0.440 1,324 OA+OB MPI-12 50-500-29230-38-00 PROD 525140 10/13/2013 1,828 PP 3,535 1,123 4,000 0.440 1,328 OA+OB MPI-13LS 50-500-29230-12-80 INJ 525140 11/17/2013 18,001 SBHP 44 2,241 1,201 4,000 0.480 2,045 OB 6. Oil Gravity: API = 14 -22 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 2. Address: 900 E. Benson Blvd Anchorage, Alaska 99508-42541. Operator: BPXA 3. Unit or Lease Name: Milne Point 4. Field and Pool: Schrader Bluff Pool 5. Datum Reference: 4000' SS 7. Gas Gravity: Air = 0.65 Exhibit 3-F Static Pressure Data Schrader Bluff Pool 8. Well Name and Number: 9. API Number 50- XXX-XXXXX-XX-XX 10. Oil (O) or Gas (G) 11. AOGCC Pool Code 12. Final Test Date 13. Shut-In Time, Hours 14. Press. Surv. Type (see instructions for codes) 15. B.H. Temp. 16. Depth Tool TVDss 17. Final Pressure at Tool Depth 18. Datum TVDss (input) 19. Pressure Gradient, psi/ft.20. Pressure at Datum (cal) Comments Zone MPI-15 50-500-29231-06-00 PROD 525140 3/1/2013 35,424 PP 3,665 1,454 4,000 0.440 1,601 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 3/31/2013 36,144 PP 3,665 1,447 4,000 0.440 1,594 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 6/1/2013 37,632 PP 3,665 1,480 4,000 0.440 1,627 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 6/30/2013 38,328 PP 3,665 1,500 4,000 0.440 1,647 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 8/1/2013 39,096 PP 3,665 1,516 4,000 0.440 1,663 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 9/1/2013 39,840 PP 3,665 1,535 4,000 0.440 1,682 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 9/30/2013 40,536 PP 3,665 1,549 4,000 0.440 1,696 OA+OB MPI-15 50-500-29231-06-00 PROD 525140 12/31/2013 42,771 PP 3,665 1,513 4,000 0.440 1,660 OA+OB MPI-19 50-500-29232-18-00 PROD 525140 1/19/2013 11,957 SBHP 76 3,760 1,300 4,000 0.360 1,387 OA+OB MPJ-01A 50-500-29220-70-01 PROD 525140 12/6/2013 370 PP 3,284 927 4,000 0.440 1,242 OA+OB MPJ-03 50-500-29220-72-00 PROD 525140 2/10/2013 3,048 PP 3,548 1,329 4,000 0.440 1,528 NA+NB+NC+NE+OA+OB MPJ-03 50-500-29220-72-00 PROD 525140 9/23/2013 1,440 PP 3,548 1,307 4,000 0.440 1,506 NA+NB+NC+NE+OA+OB MPJ-03 50-500-29220-72-00 PROD 525140 9/27/2013 1,536 SBHP 72 3,538 1,275 4,000 0.400 1,460 NA+NB+NC+NE+OA+OB MPJ-04 50-500-29220-73-00 PROD 525140 12/31/2013 37,499 PP 3,446 1,588 4,000 0.440 1,832 NB+OA+OB MPJ-05 50-500-29221-96-00 PROD 525140 3/31/2013 9,336 PP 3,689 1,322 4,000 0.440 1,459 NA+NB+NC+NE+OA+OB MPJ-05 50-500-29221-96-00 PROD 525140 9/30/2013 13,728 PP 3,689 1,347 4,000 0.440 1,484 NA+NB+NC+NE+OA+OB MPJ-05 50-500-29221-96-00 PROD 525140 12/31/2013 1,808 PP 3,689 1,342 4,000 0.440 1,479 NA+NB+NC+NE+OA+OB MPJ-09A 50-500-29224-95-01 PROD 525140 3/29/2013 38,764 SBHP 71 3,594 1,291 4,000 0.440 1,454 OA MPJ-09A 50-500-29224-95-01 PROD 525140 3/31/2013 38,808 PP 3,622 1,291 4,000 0.440 1,457 OA MPJ-17 50-500-29228-28-00 INJ 525140 4/18/2013 1,968 SBHP 87 3,970 2,153 4,000 0.420 2,166 OB MPJ-17 50-500-29228-28-00 INJ 525140 4/19/2013 5,352 SBHP 71 3,377 2,163 4,000 0.400 2,412 NB MPJ-17 50-500-29228-28-00 INJ 525140 4/19/2013 8,904 SBHP 85 3,913 2,425 4,000 0.430 2,462 OA MPJ-25 50-500-29232-07-00 PROD 525140 5/27/2013 1,656 SBHP 3,521 1,262 4,000 0.440 1,473 NB MPJ-26 50-500-29232-05-00 PROD 525140 11/8/2013 8,179 SBHP 75 3,711 1,435 4,000 0.380 1,546 NB+OA+OB MPS-03 50-500-29231-05-00 PROD 525140 5/10/2013 8,422 SBHP 79 4,008 1,639 4,000 0.390 1,636 OA MPS-04 50-500-29231-48-00 INJ 525140 12/9/2013 154 SBHP 85 3,567 2,284 4,000 0.440 2,473 OA+OB MPS-05 50-500-29231-00-00 PROD 525140 9/30/2013 21,384 PP 3,994 1,166 4,000 0.440 1,169 OA+OB MPS-05 50-500-29231-00-00 PROD 525140 11/5/2013 22,274 PP 3,994 1,126 4,000 0.440 1,129 OA+OB MPS-05 50-500-29231-00-00 PROD 525140 12/15/2013 810 PP 3,994 1,120 4,000 0.440 1,123 OA+OB MPS-06 50-500-29231-63-00 INJ 525140 7/16/2013 14,952 SBHP 80 4,000 1,766 4,000 0.440 1,766 NB MPS-08 50-500-29231-68-00 PROD 525140 4/25/2013 384 SBHP 75 3,751 2,267 4,000 0.440 2,377 Offset injector MPS-11 with MBE was online during static.NB MPS-08 50-500-29231-68-00 PROD 525140 12/31/2013 2,227 SBHP 3,781 1,610 4,000 0.440 1,707 NB MPS-12 50-500-29231-39-00 PROD 525140 12/23/2013 226 SBHP 3,982 846 4,000 0.440 854 OA+OB MPS-15 50-500-29230-61-00 INJ 525140 5/2/2013 64,638 SBHP 74 3,815 1,606 4,000 0.400 1,681 OA+OB MPS-16SS 50-500-29231-51-81 INJ 525140 1/9/2013 10,560 SBHP 80 3,953 1,690 4,000 0.430 1,710 NB MPS-31 50-500-29230-66-00 INJ 525140 1/24/2013 11,832 SBHP 74 3,784 2,117 4,000 0.400 2,203 NB MPS-32 50-500-29231-57-00 PROD 525140 3/21/2013 17,448 PP 3,754 1,500 4,000 0.440 1,608 NB MPS-32 50-500-29231-57-00 PROD 525140 9/30/2013 22,080 PP 3,754 1,584 4,000 0.440 1,692 NB MPS-32 50-500-29231-57-00 PROD 525140 12/31/2013 24,318 PP 3,754 1,579 4,000 0.440 1,687 NB MPS-34 50-500-29231-71-00 PROD 525140 3/12/2013 2,136 PP 3,996 1,388 4,000 0.440 1,390 NE+OA MPS-34 50-500-29231-71-00 PROD 525140 4/29/2013 1,008 PP 3,996 1,333 4,000 0.440 1,335 OA MPS-34 50-500-29231-71-00 PROD 525140 9/30/2013 1,080 PP 3,996 1,378 4,000 0.440 1,380 NE+OA MPS-34 50-500-29231-71-00 PROD 525140 12/31/2013 3,294 PP 3,996 1,377 4,000 0.440 1,379 NE+OA MPS-35 50-500-29231-75-00 PROD 525140 3/10/2013 1,272 PP 3,790 1,262 4,000 0.440 1,354 NB MPS-35 50-500-29231-75-00 PROD 525140 8/5/2013 144 PP 3,790 1,180 4,000 0.440 1,272 NB Average 1,615 FL Fluid Level PBU Pressure Build Up PFO Pressure Fall Off PP Pump Pressure SBHP Shut-In Bottom Hole Pressure Reservoir Engineer 21. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Printed Name Date 3/28/2014Tami Wheeler Title Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) MPB-02 1/1/2013 917 31 H2O 11,087 358 MPB-02 2/1/2013 980 28 H2O 11,388 407 MPB-02 3/1/2013 987 31 H2O 11,975 386 MPB-02 4/1/2013 896 30 H2O 6,344 211 MPB-02 5/1/2013 872 31 H2O 8,089 261 MPB-02 6/1/2013 876 30 H2O 8,715 291 MPB-02 7/1/2013 808 16 H2O 3,781 236.31 MPB-02 8/1/2013 801 31 H2O 6,210 200 MPB-02 9/1/2013 837 30 H2O 7,364 245 MPB-02 10/1/2013 878 31 H2O 9,204 297 MPB-02 11/1/2013 849 30 H2O 6,879 229 MPB-02 12/1/2013 871 31 H2O 10,167 328 MPB-27 1/1/2013 1061 31 H2O 15131 488.1 MPB-27 2/1/2013 1049 28 H2O 10166 363.07 MPB-27 3/1/2013 1068 31 H2O 9300 300 MPB-27 4/1/2013 1059 30 H2O 7617 253.9 MPB-27 5/1/2013 1055 31 H2O 6102 196.84 MPB-27 6/1/2013 1065 30 H2O 8026 267.53 MPB-27 7/1/2013 1065 31 H2O 9973 321.71 MPB-27 8/1/2013 1042 31 H2O 7766 250.52 MPB-27 9/1/2013 1071 30 H2O 8447 281.57 MPB-27 10/1/2013 1073 31 H2O 9479 305.77 MPB-27 11/1/2013 1050 30 H2O 6299 209.97 MPB-27 12/1/2013 1055 31 H2O 12091 390.03 MPE-12 1/1/2013 998 31 H2O 20766 669.87 MPE-12 2/1/2013 1014 28 H2O 16555 591.25 MPE-12 3/1/2013 1034 31 H2O 20137 649.58 MPE-12 4/1/2013 903 30 H2O 14465 482.17 MPE-12 5/1/2013 900 31 H2O 19617 632.81 MPE-12 6/1/2013 906 29 H2O 22165 764.31 MPE-12 7/1/2013 896 21 H2O 10027 477.48 MPE-12 8/1/2013 902 31 H2O 16846 543.42 MPE-12 9/1/2013 953 30 H2O 18294 609.8 MPE-12 10/1/2013 994 31 H2O 19732 636.52 MPE-12 11/1/2013 1021 30 H2O 18455 615.17 MPE-12 12/1/2013 1004 31 H2O 17,278 557.35 MPE-13B 1/1/2013 881 5 H2O 4,382 876 MPE-13B 2/1/2013 0 0 H2O 0 MPE-13B 3/1/2013 1133 30 H2O 28,731 957.7 MPE-13B 4/1/2013 1008 30 H2O 23,814 793.8 MPE-13B 5/1/2013 1049 31 H2O 29,656 956.65 MPE-13B 6/1/2013 997 30 H2O 27,725 924.17 MPE-13B 7/1/2013 851 29 H2O 18,814 648.76 MPE-13B 8/1/2013 1075 24 H2O 21,213 883.88 MPE-13B 9/1/2013 1131 30 H2O 21,819 727.3 MPE-13B 10/1/2013 1246 31 H2O 32,107 1035.71 MPE-13B 11/1/2013 1152 30 H2O 25,601 853.37 MPE-13B 12/1/2013 1248 31 H2O 27,882 899.42 Injection Rate and Pressure Data Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPE-25A 1/1/2013 0 H2O 0 MPE-25A 2/1/2013 0 H2O 0 MPE-25A 3/1/2013 0 H2O 0 MPE-25A 4/1/2013 0 H2O 0 MPE-25A 5/1/2013 0 H2O 0 MPE-25A 6/1/2013 0 H2O 0 MPE-25A 7/1/2013 0 H2O 0 MPE-25A 8/1/2013 0 H2O 0 MPE-25A 9/1/2013 0 H2O 0 MPE-25A 10/1/2013 0 H2O 0 MPE-25A 11/1/2013 0 H2O 0 MPE-25A 12/1/2013 0 H2O 0 MPE-29 1/1/2013 976 17 H2O 8305 488.53 MPE-29 2/1/2013 0 H2O 0 MPE-29 3/1/2013 0 H2O 0 MPE-29 4/1/2013 0 H2O 0 MPE-29 5/1/2013 0 H2O 0 MPE-29 6/1/2013 727 12 H2O 5471 455.92 MPE-29 7/1/2013 858 23 H2O 11418 496.43 MPE-29 8/1/2013 0 H2O 0 MPE-29 9/1/2013 691 10 H2O 4134 413.4 MPE-29 10/1/2013 0 H2O 0 MPE-29 11/1/2013 0 H2O 0 MPE-29 12/1/2013 0 H2O 0 MPG-01 1/1/2013 0 H2O 0 MPG-01 2/1/2013 0 H2O 0 MPG-01 3/1/2013 0 H2O 0 MPG-01 4/1/2013 0 H2O 0 MPG-01 5/1/2013 0 H2O 0 MPG-01 6/1/2013 0 H2O 0 MPG-01 7/1/2013 0 H2O 0 MPG-01 8/1/2013 759 9 H2O 8,412 934.67 MPG-01 9/1/2013 844 30 H2O 28,394 946.47 MPG-01 10/1/2013 797 31 H2O 14,906 480.84 MPG-01 11/1/2013 845 23 H2O 20,745 902 MPG-01 12/1/2013 955 31 H2O 28,336 914 MPG-03A 1/1/2013 0 H2O 0 MPG-03A 2/1/2013 0 H2O 0 MPG-03A 3/1/2013 0 H2O 0 MPG-03A 4/1/2013 0 H2O 0 MPG-03A 5/1/2013 0 H2O 0 MPG-03A 6/1/2013 0 H2O 0 MPG-03A 7/1/2013 1113 15 H2O 3,245 216 MPG-03A 8/1/2013 1649 31 H2O 8,898 287 MPG-03A 9/1/2013 1348 30 H2O 5,886 196 MPG-03A 10/1/2013 1706 31 H2O 7534 243.03 MPG-03A 11/1/2013 1672 30 H2O 6494 216.47 MPG-03A 12/1/2013 1733 31 H2O 6,701 216.16 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPG-05 1/1/2013 0 H2O 0 MPG-05 2/1/2013 0 H2O 0 MPG-05 3/1/2013 0 H2O 0 MPG-05 4/1/2013 0 H2O 0 MPG-05 5/1/2013 0 H2O 0 MPG-05 6/1/2013 0 H2O 0 MPG-05 7/1/2013 0 H2O 0 MPG-05 8/1/2013 0 H2O 0 MPG-05 9/1/2013 698 6 H2O 2,862 477 MPG-05 10/1/2013 0 H2O 0 MPG-05 11/1/2013 0 H2O 0 MPG-05 12/1/2013 0 H2O 0 MPG-07 1/1/2013 849 31 H2O 6,628 213.81 MPG-07 2/1/2013 990 28 H2O 9,124 325.86 MPG-07 3/1/2013 959 7 H2O 1,906 272 MPG-07 4/1/2013 0 H2O 0 MPG-07 5/1/2013 761 3 H2O 1,021 340 MPG-07 6/1/2013 1067 30 H2O 13,431 448 MPG-07 7/1/2013 1185 31 H2O 13,902 448 MPG-07 8/1/2013 1172 31 H2O 11,112 358 MPG-07 9/1/2013 1298 30 H2O 12,463 415 MPG-07 10/1/2013 1326 13 H2O 4,464 343 MPG-07 11/1/2013 1469 30 H2O 9,118 303.93 MPG-07 12/1/2013 1611 31 H2O 10,815 349 MPG-09 1/1/2013 0 H2O 0 MPG-09 2/1/2013 0 H2O 0 MPG-09 3/1/2013 552 21 H2O 7,324 349 MPG-09 4/1/2013 670 30 H2O 14,508 484 MPG-09 5/1/2013 882 31 H2O 15,143 488 MPG-09 6/1/2013 1026 30 H2O 14,896 496.53 MPG-09 7/1/2013 1033 31 H2O 15,532 501 MPG-09 8/1/2013 1034 31 H2O 14,356 463 MPG-09 9/1/2013 1030 30 H2O 9,990 333 MPG-09 10/1/2013 1051 31 H2O 11,578 373 MPG-09 11/1/2013 1053 30 H2O 10594 353.13 MPG-09 12/1/2013 1070 31 H2O 12,051 388.74 MPG-10 1/1/2013 0 H2O 0 MPG-10 2/1/2013 0 H2O 0 MPG-10 3/1/2013 630 31 H2O 17,830 575.16 MPG-10 4/1/2013 694 30 H2O 21,513 717.1 MPG-10 5/1/2013 705 31 H2O 20,763 669.77 MPG-10 6/1/2013 712 30 H2O 19,405 646.83 MPG-10 7/1/2013 704 26 H2O 17,067 656.42 MPG-10 8/1/2013 717 20 H2O 14,928 746.4 MPG-10 9/1/2013 693 30 H2O 16,905 563.5 MPG-10 10/1/2013 695 21 H2O 13,739 654.24 MPG-10 11/1/2013 741 30 H2O 24,111 803.7 MPG-10 12/1/2013 752 31 H2O 22,432 723.61 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPG-13 1/1/2013 0 H2O 0 MPG-13 2/1/2013 0 H2O 0 MPG-13 3/1/2013 1011 31 H2O 21,481 692.94 MPG-13 4/1/2013 1034 30 H2O 16832 561.07 MPG-13 5/1/2013 1025 30 H2O 19841 661.37 MPG-13 6/1/2013 1089 30 H2O 22227 740.9 MPG-13 7/1/2013 1053 31 H2O 18,669 602 MPG-13 8/1/2013 1063 30 H2O 20,385 680 MPG-13 9/1/2013 1050 13 H2O 8,504 654 MPG-13 10/1/2013 1053 21 H2O 13,384 637 MPG-13 11/1/2013 1090 30 H2O 22,975 766 MPG-13 12/1/2013 1098 31 H2O 18,834 608 MPG-17 1/1/2013 842 31 H2O 13728 442.84 MPG-17 2/1/2013 924 28 H2O 18,000 643 MPG-17 3/1/2013 908 31 H2O 18,354 592 MPG-17 4/1/2013 910 30 H2O 18748 624.93 MPG-17 5/1/2013 883 31 H2O 17367 560.23 MPG-17 6/1/2013 933 30 H2O 21225 707.5 MPG-17 7/1/2013 926 31 H2O 20700 667.74 MPG-17 8/1/2013 899 31 H2O 15067 486.03 MPG-17 9/1/2013 901 30 H2O 14422 480.73 MPG-17 10/1/2013 903 31 H2O 18056 582.45 MPG-17 11/1/2013 903 30 H2O 19471 649.03 MPG-17 12/1/2013 945 31 H2O 21709 700.29 MPG-19 1/1/2013 0 H2O 0 MPG-19 2/1/2013 0 H2O 0 MPG-19 3/1/2013 0 H2O 0 MPG-19 4/1/2013 0 H2O 0 MPG-19 5/1/2013 0 H2O 0 MPG-19 6/1/2013 0 H2O 0 MPG-19 7/1/2013 0 H2O 0 MPG-19 8/1/2013 0 H2O 0 MPG-19 9/1/2013 1644 28 H2O 7,969 284.61 MPG-19 10/1/2013 1952 31 H2O 8,702 280.71 MPG-19 11/1/2013 1622 30 H2O 6,272 209.07 MPG-19 12/1/2013 1427 31 H2O 5,559 179.32 MPH-11 1/1/2013 0 H2O 0 MPH-11 2/1/2013 0 H2O 0 MPH-11 3/1/2013 0 H2O 0 MPH-11 4/1/2013 0 H2O 0 MPH-11 5/1/2013 0 H2O 0 MPH-11 6/1/2013 0 H2O 0 MPH-11 7/1/2013 0 H2O 0 MPH-11 8/1/2013 0 H2O 0 MPH-11 9/1/2013 0 H2O 0 MPH-11 10/1/2013 0 H2O 0 MPH-11 11/1/2013 0 H2O 0 MPH-11 12/1/2013 0 H2O 0 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPH-12 1/1/2013 0 H2O 0 MPH-12 2/1/2013 0 H2O 0 MPH-12 3/1/2013 0 H2O 0 MPH-12 4/1/2013 0 H2O 0 MPH-12 5/1/2013 0 H2O 0 MPH-12 6/1/2013 856 26 H2O 8,400 323.08 MPH-12 7/1/2013 861 31 H2O 9,549 308.03 MPH-12 8/1/2013 880 31 H2O 9,156 295.35 MPH-12 9/1/2013 918 30 H2O 6,985 232.83 MPH-12 10/1/2013 955 31 H2O 9,820 316.77 MPH-12 11/1/2013 967 30 H2O 11,537 384.57 MPH-12 12/1/2013 961 31 H2O 8,370 270 MPH-15 1/1/2013 1263 16 H2O 9,909 619.31 MPH-15 2/1/2013 0 H2O 0 MPH-15 3/1/2013 891 10 H2O 6350 635 MPH-15 4/1/2013 1195 19 H2O 10,657 560.89 MPH-15 5/1/2013 1537 31 H2O 14930 481.61 MPH-15 6/1/2013 1436 30 H2O 13618 453.93 MPH-15 7/1/2013 1437 29 H2O 10334 356.34 MPH-15 8/1/2013 1446 31 H2O 17,603 567.84 MPH-15 9/1/2013 1315 30 H2O 15,902 530.07 MPH-15 10/1/2013 1185 31 H2O 10,006 322.77 MPH-15 11/1/2013 1101 18 H2O 5,340 297 MPH-15 12/1/2013 763 31 H2O 6,961 225 MPH-17 1/1/2013 1236 31 H2O 12,829 413.84 MPH-17 2/1/2013 1107 14 H2O 4,038 288.43 MPH-17 3/1/2013 1305 31 H2O 26,085 841 MPH-17 4/1/2013 1239 30 H2O 23,483 782.77 MPH-17 5/1/2013 1244 31 H2O 27,919 900.61 MPH-17 6/1/2013 1207 30 H2O 27,339 911.3 MPH-17 7/1/2013 1173 31 H2O 26,758 863.16 MPH-17 8/1/2013 1095 31 H2O 25,752 830.71 MPH-17 9/1/2013 1184 30 H2O 28,312 943.73 MPH-17 10/1/2013 1116 31 H2O 25,937 837 MPH-17 11/1/2013 1157 30 H2O 28,201 940 MPH-17 12/1/2013 1187 31 H2O 29,556 953 MPI-02 1/1/2013 0 H2O 0 MPI-02 2/1/2013 0 H2O 0 MPI-02 3/1/2013 0 H2O 0 MPI-02 4/1/2013 1039 14 H2O 12,538 895.57 MPI-02 5/1/2013 960 31 H2O 17,037 549.58 MPI-02 6/1/2013 963 30 H2O 14,496 483 MPI-02 7/1/2013 935 31 H2O 24,397 787 MPI-02 8/1/2013 938 31 H2O 25,555 824 MPI-02 9/1/2013 1018 30 H2O 31,572 1,052 MPI-02 10/1/2013 1001 31 H2O 29,288 945 MPI-02 11/1/2013 979 13 H2O 9,627 741 MPI-02 12/1/2013 0 H2O 0 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPI-05 1/1/2013 0 H2O 0 MPI-05 2/1/2013 0 H2O 0 MPI-05 3/1/2013 0 H2O 0 MPI-05 4/1/2013 0 H2O 0 MPI-05 5/1/2013 0 H2O 0 MPI-05 6/1/2013 0 H2O 0 MPI-05 7/1/2013 0 H2O 0 MPI-05 8/1/2013 0 H2O 0 MPI-05 9/1/2013 0 H2O 0 MPI-05 10/1/2013 0 H2O 0 MPI-05 11/1/2013 0 H2O 0 MPI-05 12/1/2013 0 H2O 0 MPI-08 1/1/2013 1020 31 H2O 43,775 1,412 MPI-08 2/1/2013 1216 28 H2O 40,831 1,458 MPI-08 3/1/2013 1191 31 H2O 41,706 1345.35 MPI-08 4/1/2013 927 30 H2O 23,161 772.03 MPI-08 5/1/2013 966 15 H2O 7772 518.13 MPI-08 6/1/2013 1165 30 H2O 25509 850.3 MPI-08 7/1/2013 1148 31 H2O 26,042 840.06 MPI-08 8/1/2013 878 31 H2O 22,425 723.39 MPI-08 9/1/2013 939 30 H2O 24,830 827.67 MPI-08 10/1/2013 935 31 H2O 24,201 780.68 MPI-08 11/1/2013 1064 30 H2O 26,847 894.9 MPI-08 12/1/2013 889 26 H2O 26,799 1030.73 MPI-09 1/1/2013 1179 31 H2O 30,767 992.48 MPI-09 2/1/2013 1315 28 H2O 29,685 1060.18 MPI-09 3/1/2013 1338 31 H2O 32,297 1041.84 MPI-09 4/1/2013 1174 30 H2O 25,411 847.03 MPI-09 5/1/2013 1106 22 H2O 19,435 883.41 MPI-09 6/1/2013 1284 30 H2O 30,553 1,018 MPI-09 7/1/2013 1237 31 H2O 27,806 897 MPI-09 8/1/2013 1028 31 H2O 23,995 774 MPI-09 9/1/2013 980 30 H2O 21,681 723 MPI-09 10/1/2013 1120 27 H2O 25,526 945 MPI-09 11/1/2013 1277 30 H2O 39,956 1,332 MPI-09 12/1/2013 1366 31 H2O 43528 1404.13 MPI-10 1/1/2013 0 H2O 0 MPI-10 2/1/2013 0 H2O 0 MPI-10 3/1/2013 0 H2O 0 MPI-10 4/1/2013 0 H2O 0 MPI-10 5/1/2013 0 H2O 0 MPI-10 6/1/2013 0 H2O 0 MPI-10 7/1/2013 0 H2O 0 MPI-10 8/1/2013 0 H2O 0 MPI-10 9/1/2013 0 H2O 0 MPI-10 10/1/2013 0 H2O 0 MPI-10 11/1/2013 0 H2O 0 MPI-10 12/1/2013 0 H2O 0 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPI-13 1/1/2013 0 H2O 0 MPI-13 2/1/2013 0 H2O 0 MPI-13 3/1/2013 0 H2O 0 MPI-13 4/1/2013 0 H2O 0 MPI-13 5/1/2013 0 H2O 0 MPI-13 6/1/2013 0 H2O 0 MPI-13 7/1/2013 0 H2O 0 MPI-13 8/1/2013 0 H2O 0 MPI-13 9/1/2013 0 H2O 0 MPI-13 10/1/2013 0 H2O 0 MPI-13 11/1/2013 0 H2O 0 MPI-13 12/1/2013 0 H2O 0 MPI-16 1/1/2013 988 29 H2O 30,720 1,059 MPI-16 2/1/2013 964 28 H2O 35,512 1,268 MPI-16 3/1/2013 1003 31 H2O 45,543 1,469 MPI-16 4/1/2013 975 30 H2O 40,338 1,345 MPI-16 5/1/2013 1032 31 H2O 42,660 1,376 MPI-16 6/1/2013 1005 30 H2O 39773 1325.77 MPI-16 7/1/2013 972 31 H2O 39802 1283.94 MPI-16 8/1/2013 900 31 H2O 31784 1025.29 MPI-16 9/1/2013 981 30 H2O 42219 1407.3 MPI-16 10/1/2013 978 31 H2O 45,113 1455.26 MPI-16 11/1/2013 967 20 H2O 27,647 1382.35 MPI-16 12/1/2013 973 31 H2O 39,039 1259.32 MPI-18 1/1/2013 1155 31 H2O 26,590 857.74 MPI-18 2/1/2013 1005 28 H2O 27,559 984.25 MPI-18 3/1/2013 1018 31 H2O 32,292 1041.68 MPI-18 4/1/2013 1086 30 H2O 35,509 1183.63 MPI-18 5/1/2013 1086 31 H2O 31,182 1005.87 MPI-18 6/1/2013 1141 30 H2O 33,769 1125.63 MPI-18 7/1/2013 1181 31 H2O 32687 1054.42 MPI-18 8/1/2013 1133 31 H2O 27089 873.84 MPI-18 9/1/2013 1106 30 H2O 19256 641.87 MPI-18 10/1/2013 1193 30 H2O 23,372 779.07 MPI-18 11/1/2013 1267 30 H2O 34,172 1139.07 MPI-18 12/1/2013 1620 31 H2O 20,411 658.42 MPJ-02 1/1/2013 0 H2O 0 MPJ-02 2/1/2013 0 H2O 0 MPJ-02 3/1/2013 0 H2O 0 MPJ-02 4/1/2013 0 H2O 0 MPJ-02 5/1/2013 0 H2O 0 MPJ-02 6/1/2013 0 H2O 0 MPJ-02 7/1/2013 722 24 H2O 6,280 262 MPJ-02 8/1/2013 740 31 H2O 8,564 276 MPJ-02 9/1/2013 745 30 H2O 7,055 235.17 MPJ-02 10/1/2013 767 22 H2O 7,049 320 MPJ-02 11/1/2013 0 H2O 0 MPJ-02 12/1/2013 0 H2O 0 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPJ-15 1/1/2013 669 31 H2O 15,168 489 MPJ-15 2/1/2013 729 28 H2O 17248 616 MPJ-15 3/1/2013 724 31 H2O 18988 612.52 MPJ-15 4/1/2013 705 30 H2O 16461 548.7 MPJ-15 5/1/2013 729 31 H2O 16,937 546 MPJ-15 6/1/2013 740 30 H2O 16,783 559 MPJ-15 7/1/2013 736 31 H2O 16,569 534 MPJ-15 8/1/2013 750 31 H2O 19865 640.81 MPJ-15 9/1/2013 738 30 H2O 15939 531.3 MPJ-15 10/1/2013 794 31 H2O 16168 521.55 MPJ-15 11/1/2013 822 20 H2O 11,536 576.8 MPJ-15 12/1/2013 902 13 H2O 7,552 580.92 MPJ-17 1/1/2013 818 26 H2O 11,156 429.08 MPJ-17 2/1/2013 0 H2O 0 MPJ-17 3/1/2013 0 H2O 0 MPJ-17 4/1/2013 896 11 H2O 9,194 835.82 MPJ-17 5/1/2013 987 31 H2O 27,335 881.77 MPJ-17 6/1/2013 1017 30 H2O 26,895 896.5 MPJ-17 7/1/2013 1015 31 H2O 26,569 857.06 MPJ-17 8/1/2013 1007 31 H2O 23,881 770 MPJ-17 9/1/2013 1046 30 H2O 25,858 862 MPJ-17 10/1/2013 1026 31 H2O 25,972 838 MPJ-17 11/1/2013 1070 30 H2O 28,106 937 MPJ-17 12/1/2013 1051 31 H2O 26,725 862 MPJ-18 1/1/2013 932 31 H2O 30,998 1,000 MPJ-18 2/1/2013 961 28 H2O 29,873 1,067 MPJ-18 3/1/2013 916 31 H2O 27,217 878 MPJ-18 4/1/2013 950 30 H2O 30,833 1,028 MPJ-18 5/1/2013 1060 31 H2O 29,324 946 MPJ-18 6/1/2013 953 30 H2O 26,687 890 MPJ-18 7/1/2013 896 31 H2O 22,701 732 MPJ-18 8/1/2013 905 31 H2O 24,070 776 MPJ-18 9/1/2013 930 30 H2O 26,723 890.77 MPJ-18 10/1/2013 872 31 H2O 22,492 725.55 MPJ-18 11/1/2013 898 12 H2O 10,519 876.58 MPJ-18 12/1/2013 1026 18 H2O 11,577 643.17 MPJ-19A 1/1/2013 677 31 H2O 20,365 656.94 MPJ-19A 2/1/2013 698 28 H2O 17521 625.75 MPJ-19A 3/1/2013 760 31 H2O 22,460 724.52 MPJ-19A 4/1/2013 741 30 H2O 19,867 662 MPJ-19A 5/1/2013 797 31 H2O 38,862 1,254 MPJ-19A 6/1/2013 850 30 H2O 34,868 1,162 MPJ-19A 7/1/2013 731 31 H2O 31,175 1,006 MPJ-19A 8/1/2013 708 31 H2O 23,834 769 MPJ-19A 9/1/2013 798 30 H2O 33,522 1,117 MPJ-19A 10/1/2013 765 31 H2O 29,543 953 MPJ-19A 11/1/2013 814 30 H2O 30,126 1,004 MPJ-19A 12/1/2013 838 31 H2O 36,993 1,193 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPJ-20A 1/1/2013 0 H2O 0 MPJ-20A 2/1/2013 0 H2O 0 MPJ-20A 3/1/2013 0 H2O 0 MPJ-20A 4/1/2013 0 H2O 0 MPJ-20A 5/1/2013 0 H2O 0 MPJ-20A 6/1/2013 0 H2O 0 MPJ-20A 7/1/2013 0 H2O 0 MPJ-20A 8/1/2013 0 H2O 0 MPJ-20A 9/1/2013 0 H2O 0 MPJ-20A 10/1/2013 0 H2O 0 MPJ-20A 11/1/2013 0 H2O 0 MPJ-20A 12/1/2013 0 H2O 0 MPS-01B 1/1/2013 0 H2O 0 MPS-01B 2/1/2013 0 H2O 0 MPS-01B 3/1/2013 0 H2O 0 MPS-01B 4/1/2013 0 H2O 0 MPS-01B 5/1/2013 0 H2O 0 MPS-01B 6/1/2013 0 H2O 0 MPS-01B 7/1/2013 0 H2O 0 MPS-01B 8/1/2013 0 H2O 0 MPS-01B 9/1/2013 0 H2O 0 MPS-01B 10/1/2013 0 H2O 0 MPS-01B 11/1/2013 0 H2O 0 MPS-01B 12/1/2013 0 H2O 0 MPS-02 1/1/2013 991 31 H2O 35309 1139 MPS-02 2/1/2013 1035 28 H2O 34,815 1,243 MPS-02 3/1/2013 1071 31 H2O 39,380 1,270 MPS-02 4/1/2013 1028 30 H2O 31,620 1,054 MPS-02 5/1/2013 1037 31 H2O 31,375 1,012 MPS-02 6/1/2013 990 30 H2O 27,283 909 MPS-02 7/1/2013 936 31 H2O 26,882 867 MPS-02 8/1/2013 939 31 H2O 27,802 897 MPS-02 9/1/2013 976 30 H2O 28,443 948 MPS-02 10/1/2013 939 24 H2O 20,664 861 MPS-02 11/1/2013 999 21 H2O 21,976 1046.48 MPS-02 12/1/2013 0 H2O 0 MPS-04 1/1/2013 1172 31 H2O 33,129 1068.68 MPS-04 2/1/2013 1224 28 H2O 32,139 1147.82 MPS-04 3/1/2013 1228 31 H2O 35,109 1132.55 MPS-04 4/1/2013 1216 30 H2O 33,587 1,120 MPS-04 5/1/2013 1169 31 H2O 31755 1024.35 MPS-04 6/1/2013 1555 30 H2O 50048 1668.27 MPS-04 7/1/2013 1730 31 H2O 60823 1962.03 MPS-04 8/1/2013 1678 30 H2O 41215 1373.83 MPS-04 9/1/2013 1809 30 H2O 43884 1462.8 MPS-04 10/1/2013 1241 24 H2O 44757 1864.88 MPS-04 11/1/2013 1302 30 H2O 56937 1897.9 MPS-04 12/1/2013 1050 11 H2O 19093 1735.73 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPS-06 1/1/2013 0 H2O 0 MPS-06 2/1/2013 0 H2O 0 MPS-06 3/1/2013 0 H2O 0 MPS-06 4/1/2013 0 H2O 0 MPS-06 5/1/2013 0 H2O 0 MPS-06 6/1/2013 0 H2O 0 MPS-06 7/1/2013 0 H2O 0 MPS-06 8/1/2013 0 H2O 0 MPS-06 9/1/2013 0 H2O 0 MPS-06 10/1/2013 0 H2O 0 MPS-06 11/1/2013 0 H2O 0 MPS-06 12/1/2013 0 H2O 0 MPS-07 1/1/2013 0 H2O 0 MPS-07 2/1/2013 0 H2O 0 MPS-07 3/1/2013 0 H2O 0 MPS-07 4/1/2013 0 H2O 0 MPS-07 5/1/2013 0 H2O 0 MPS-07 6/1/2013 0 H2O 0 MPS-07 7/1/2013 0 H2O 0 MPS-07 8/1/2013 0 H2O 0 MPS-07 9/1/2013 0 H2O 0 MPS-07 10/1/2013 0 H2O 0 MPS-07 11/1/2013 0 H2O 0 MPS-07 12/1/2013 0 H2O 0 MPS-09 1/1/2013 0 H2O 0 MPS-09 2/1/2013 0 H2O 0 MPS-09 3/1/2013 0 H2O 0 MPS-09 4/1/2013 0 H2O 0 MPS-09 5/1/2013 0 H2O 0 MPS-09 6/1/2013 0 H2O 0 MPS-09 7/1/2013 0 H2O 0 MPS-09 8/1/2013 0 H2O 0 MPS-09 9/1/2013 0 H2O 0 MPS-09 10/1/2013 0 H2O 0 MPS-09 11/1/2013 0 H2O 0 MPS-09 12/1/2013 0 H2O 0 MPS-10A 1/1/2013 0 H2O 0 MPS-10A 2/1/2013 0 H2O 0 MPS-10A 3/1/2013 0 H2O 0 MPS-10A 4/1/2013 0 H2O 0 MPS-10A 5/1/2013 0 H2O 0 MPS-10A 6/1/2013 0 H2O 0 MPS-10A 7/1/2013 0 H2O 0 MPS-10A 8/1/2013 0 H2O 0 MPS-10A 9/1/2013 0 H2O 0 MPS-10A 10/1/2013 0 H2O 0 MPS-10A 11/1/2013 0 H2O 0 MPS-10A 12/1/2013 0 H2O 0 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPS-11 1/1/2013 1016 31 H2O 9,903 319 MPS-11 2/1/2013 1069 28 H2O 8,748 312 MPS-11 3/1/2013 1044 31 H2O 10,731 346 MPS-11 4/1/2013 982 30 H2O 9,375 313 MPS-11 5/1/2013 974 8 H2O 2,350 294 MPS-11 6/1/2013 0 H2O 0 MPS-11 7/1/2013 0 H2O 0 MPS-11 8/1/2013 0 H2O 0 MPS-11 9/1/2013 0 H2O 0 MPS-11 10/1/2013 674 10 H2O 4,044 404 MPS-11 11/1/2013 849 30 H2O 15,614 520 MPS-11 12/1/2013 884 31 H2O 15,849 511 MPS-13 1/1/2013 0 H2O 0 MPS-13 2/1/2013 0 H2O 0 MPS-13 3/1/2013 0 H2O 0 MPS-13 4/1/2013 0 H2O 0 MPS-13 5/1/2013 0 H2O 0 MPS-13 6/1/2013 0 H2O 0 MPS-13 7/1/2013 0 H2O 0 MPS-13 8/1/2013 0 H2O 0 MPS-13 9/1/2013 0 H2O 0 MPS-13 10/1/2013 0 H2O 0 MPS-13 11/1/2013 0 H2O 0 MPS-13 12/1/2013 0 H2O 0 MPS-14 1/1/2013 854 31 H2O 14,152 457 MPS-14 2/1/2013 892 28 H2O 15,926 569 MPS-14 3/1/2013 926 31 H2O 19,126 616.97 MPS-14 4/1/2013 921 30 H2O 15,414 513.8 MPS-14 5/1/2013 934 31 H2O 18,742 605 MPS-14 6/1/2013 921 30 H2O 16,207 540 MPS-14 7/1/2013 938 31 H2O 17,030 549 MPS-14 8/1/2013 911 31 H2O 13,594 439 MPS-14 9/1/2013 979 30 H2O 16,030 534 MPS-14 10/1/2013 976 31 H2O 16,500 532.26 MPS-14 11/1/2013 979 30 H2O 16,879 563 MPS-14 12/1/2013 1011 31 H2O 18,364 592 MPS-15 1/1/2013 0 H2O 0 MPS-15 2/1/2013 0 H2O 0 MPS-15 3/1/2013 0 H2O 0 MPS-15 4/1/2013 0 H2O 0 MPS-15 5/1/2013 0 H2O 0 MPS-15 6/1/2013 0 H2O 0 MPS-15 7/1/2013 0 H2O 0 MPS-15 8/1/2013 0 H2O 0 MPS-15 9/1/2013 804 15 H2O 6,192 413 MPS-15 10/1/2013 742 31 H2O 8,351 269 MPS-15 11/1/2013 892 30 H2O 9,958 332 MPS-15 12/1/2013 966 31 H2O 10,696 345 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPS-16 1/1/2013 838 31 H2O 27,863 899 MPS-16 2/1/2013 903 28 H2O 30,898 1,104 MPS-16 3/1/2013 952 31 H2O 36,036 1,162 MPS-16 4/1/2013 981 30 H2O 29,760 992 MPS-16 5/1/2013 1052 31 H2O 18,271 589 MPS-16 6/1/2013 1004 30 H2O 15,869 529 MPS-16 7/1/2013 1055 30 H2O 17,695 590 MPS-16 8/1/2013 1004 31 H2O 15,006 484 MPS-16 9/1/2013 1025 30 H2O 17,298 577 MPS-16 10/1/2013 983 31 H2O 15,016 484 MPS-16 11/1/2013 1024 30 H2O 14,495 483 MPS-16 12/1/2013 1039 31 H2O 21,782 703 MPS-18 1/1/2013 909 31 H2O 22,635 730 MPS-18 2/1/2013 976 28 H2O 24,691 882 MPS-18 3/1/2013 1009 31 H2O 25,407 819.58 MPS-18 4/1/2013 969 30 H2O 16,706 556.87 MPS-18 5/1/2013 933 31 H2O 19,410 626.13 MPS-18 6/1/2013 901 30 H2O 27,595 919.83 MPS-18 7/1/2013 1007 30 H2O 32,615 1087.17 MPS-18 8/1/2013 796 24 H2O 15,662 652.58 MPS-18 9/1/2013 972 30 H2O 34,186 1139.53 MPS-18 10/1/2013 977 23 H2O 25,165 1094.13 MPS-18 11/1/2013 730 10 H2O 5,466 546.6 MPS-18 12/1/2013 820 31 H2O 23,446 756.32 MPS-20 1/1/2013 725 31 H2O 42,331 1365.52 MPS-20 2/1/2013 729 28 H2O 36,875 1316.96 MPS-20 3/1/2013 711 31 H2O 37,825 1220.16 MPS-20 4/1/2013 698 30 H2O 24,598 819.93 MPS-20 5/1/2013 686 31 H2O 22769 734.48 MPS-20 6/1/2013 635 13 H2O 8543 657.15 MPS-20 7/1/2013 0 H2O 0 MPS-20 8/1/2013 0 H2O 0 MPS-20 9/1/2013 0 H2O 0 MPS-20 10/1/2013 0 H2O 0 MPS-20 11/1/2013 0 H2O 0 MPS-20 12/1/2013 0 H2O 0 MPS-21 1/1/2013 0 H2O 0 MPS-21 2/1/2013 0 H2O 0 MPS-21 3/1/2013 0 H2O 0 MPS-21 4/1/2013 0 H2O 0 MPS-21 5/1/2013 0 H2O 0 MPS-21 6/1/2013 0 H2O 0 MPS-21 7/1/2013 0 H2O 0 MPS-21 8/1/2013 0 H2O 0 MPS-21 9/1/2013 0 H2O 0 MPS-21 10/1/2013 0 H2O 0 MPS-21 11/1/2013 0 H2O 0 MPS-21 12/1/2013 0 H2O 0 Exhibit 3-G Milne Point Field Schrader Bluff Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) Injection Rate and Pressure Data MPS-26 1/1/2013 820 20 H2O 22,072 1,104 MPS-26 2/1/2013 827 28 H2O 31,706 1,132 MPS-26 3/1/2013 816 31 H2O 35,962 1,160 MPS-26 4/1/2013 800 30 H2O 34,851 1,162 MPS-26 5/1/2013 792 31 H2O 35,230 1,136 MPS-26 6/1/2013 772 30 H2O 34,679 1,156 MPS-26 7/1/2013 747 30 H2O 33,769 1,126 MPS-26 8/1/2013 693 24 H2O 21,323 888 MPS-26 9/1/2013 625 2 H2O 287 144 MPS-26 10/1/2013 941 31 H2O 17,180 554 MPS-26 11/1/2013 1066 30 H2O 25,176 839 MPS-26 12/1/2013 1039 31 H2O 26,353 850 MPS-30 1/1/2013 957 31 H2O 7,675 248 MPS-30 2/1/2013 965 28 H2O 8,454 302 MPS-30 3/1/2013 879 31 H2O 7,317 236 MPS-30 4/1/2013 882 30 H2O 8,112 270 MPS-30 5/1/2013 876 31 H2O 8,407 271 MPS-30 6/1/2013 876 30 H2O 8,745 292 MPS-30 7/1/2013 881 31 H2O 9,948 321 MPS-30 8/1/2013 780 31 H2O 6,506 210 MPS-30 9/1/2013 884 30 H2O 10,953 365 MPS-30 10/1/2013 867 31 H2O 18,784 606 MPS-30 11/1/2013 878 30 H2O 22,731 758 MPS-30 12/1/2013 882 31 H2O 9,953 321 MPS-31 1/1/2013 1163 27 H2O 13,709 508 MPS-31 2/1/2013 1117 28 H2O 11,462 409 MPS-31 3/1/2013 1201 31 H2O 19,210 620 MPS-31 4/1/2013 1202 30 H2O 18,089 603 MPS-31 5/1/2013 1248 31 H2O 20,528 662.19 MPS-31 6/1/2013 1222 30 H2O 16,706 557 MPS-31 7/1/2013 1109 29 H2O 15,078 520 MPS-31 8/1/2013 1172 31 H2O 19,858 641 MPS-31 9/1/2013 1114 15 H2O 12,934 862 MPS-31 10/1/2013 1243 31 H2O 28,842 930 MPS-31 11/1/2013 1240 26 H2O 22,610 870 MPS-31 12/1/2013 1287 31 H2O 29,144 940.13 MPS-33A 1/1/2013 961 11 H2O 3,367 306.09 MPS-33A 2/1/2013 1038 28 H2O 9,798 349.93 MPS-33A 3/1/2013 1019 27 H2O 7,693 284.93 MPS-33A 4/1/2013 1079 30 H2O 9,675 322.5 MPS-33A 5/1/2013 1078 31 H2O 10,276 331.48 MPS-33A 6/1/2013 1043 30 H2O 10,448 348.27 MPS-33A 7/1/2013 898 31 H2O 8,957 288.94 MPS-33A 8/1/2013 747 24 H2O 6,719 279.96 MPS-33A 9/1/2013 761 15 H2O 4,083 272.2 MPS-33A 10/1/2013 894 31 H2O 8,687 280.23 MPS-33A 11/1/2013 985 30 H2O 12,073 402.43 MPS-33A 12/1/2013 1052 31 H2O 14,985 483.39 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 01/01/13 0.87 1.41 1.10 01/02/13 0.89 1.38 1.14 01/03/13 0.89 1.38 1.13 01/04/13 0.88 1.40 1.15 01/05/13 0.91 1.35 1.20 01/06/13 0.88 1.29 1.16 01/07/13 0.87 1.04 1.13 01/08/13 0.87 1.10 1.11 01/09/13 0.90 1.40 1.17 01/10/13 0.93 1.36 1.19 01/11/13 0.92 1.30 1.19 01/12/13 0.92 1.22 1.14 01/13/13 0.94 1.31 1.14 01/14/13 0.91 1.17 1.25 01/15/13 0.52 1.58 1.04 01/16/13 0.67 1.43 0.99 01/17/13 0.82 1.41 1.06 01/18/13 0.91 1.45 1.16 01/19/13 0.95 1.45 1.17 01/20/13 0.91 1.34 1.17 01/21/13 0.95 1.37 1.12 01/22/13 0.95 1.34 1.16 01/23/13 0.92 1.29 1.15 01/24/13 0.91 1.30 1.09 01/25/13 0.90 1.09 1.01 01/26/13 0.89 1.10 0.98 01/27/13 0.90 1.28 0.99 01/28/13 0.89 1.35 0.97 01/29/13 0.89 1.35 0.97 01/30/13 0.87 1.35 0.92 01/31/13 0.90 1.35 0.92 02/01/13 0.91 1.31 0.94 02/02/13 0.93 1.33 1.00 02/03/13 0.92 1.39 1.00 02/04/13 0.94 1.28 1.01 02/05/13 0.93 1.29 0.98 02/06/13 0.92 1.20 0.98 02/07/13 0.92 1.25 1.03 02/08/13 0.93 1.27 1.05 02/09/13 0.96 1.21 1.05 02/10/13 0.97 1.02 1.05 02/11/13 0.95 0.99 0.99 02/12/13 0.96 0.97 0.99 02/13/13 0.95 0.98 0.98 02/14/13 0.95 1.23 0.98 02/15/13 0.96 1.28 1.00 02/16/13 0.95 1.25 1.02 02/17/13 0.93 1.15 1.12 Milne Point Unit Allocation Factor Report 1/1/2013 - 12/31/2013 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 02/18/13 0.96 1.13 1.21 02/19/13 0.95 1.04 1.20 02/20/13 0.96 0.84 1.17 02/21/13 0.97 0.85 1.15 02/22/13 0.96 0.85 1.09 02/23/13 0.95 0.84 1.15 02/24/13 0.97 0.87 1.07 02/25/13 0.95 0.87 1.06 02/26/13 0.95 0.85 1.06 02/27/13 0.93 0.91 1.03 02/28/13 0.97 0.88 1.09 03/01/13 0.95 0.86 1.14 03/02/13 0.96 0.87 1.16 03/03/13 0.94 0.88 1.22 03/04/13 0.97 0.93 1.18 03/05/13 0.96 0.92 1.17 03/06/13 0.98 0.97 1.21 03/07/13 0.97 0.94 1.29 03/08/13 0.98 1.09 1.28 03/09/13 0.99 1.08 1.29 03/10/13 0.94 0.84 1.31 03/11/13 0.96 0.93 1.29 03/12/13 0.95 0.88 1.23 03/13/13 0.93 0.88 1.18 03/14/13 0.92 0.86 1.13 03/15/13 0.91 0.86 1.02 03/16/13 0.84 0.88 1.04 03/17/13 0.95 0.95 1.28 03/18/13 0.93 1.05 1.06 03/19/13 0.92 0.90 1.11 03/20/13 0.94 0.88 1.09 03/21/13 0.92 0.88 1.15 03/22/13 0.91 0.92 1.16 03/23/13 0.91 0.89 1.17 03/24/13 0.94 0.92 1.13 03/25/13 0.92 0.96 1.12 03/26/13 0.93 1.14 1.12 03/27/13 0.93 1.19 1.08 03/28/13 0.93 1.17 1.09 03/29/13 0.93 0.91 1.11 03/30/13 0.93 0.92 1.13 03/31/13 0.93 0.92 1.11 04/01/13 0.90 0.89 1.13 04/02/13 0.91 0.86 1.10 04/03/13 0.92 0.88 1.14 04/04/13 0.95 0.89 1.19 04/05/13 0.94 0.88 1.20 04/06/13 0.93 0.90 1.15 04/07/13 0.94 0.89 1.14 04/08/13 0.93 0.91 1.18 04/09/13 0.79 0.84 1.11 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 04/10/13 0.95 0.94 1.11 04/11/13 0.98 1.09 1.13 04/12/13 0.96 0.92 1.13 04/13/13 0.97 0.88 1.11 04/14/13 0.96 0.91 1.12 04/15/13 1.00 0.89 1.13 04/16/13 0.96 0.89 1.14 04/17/13 0.97 0.90 1.15 04/18/13 0.96 0.86 1.16 04/19/13 0.93 0.86 1.11 04/20/13 0.96 0.87 1.12 04/21/13 0.97 0.87 1.15 04/22/13 0.96 0.91 1.16 04/23/13 0.94 0.91 1.20 04/24/13 0.93 0.88 1.22 04/25/13 0.88 0.91 1.17 04/26/13 0.90 0.90 1.19 04/27/13 0.92 0.90 1.23 04/28/13 0.91 0.89 1.18 04/29/13 0.87 0.92 1.20 04/30/13 0.82 0.89 1.18 05/01/13 0.93 0.88 1.25 05/02/13 0.92 0.92 1.28 05/03/13 0.92 0.93 1.26 05/04/13 0.94 0.91 1.28 05/05/13 0.93 0.90 1.26 05/06/13 0.93 0.91 1.27 05/07/13 0.93 0.90 1.23 05/08/13 0.92 0.89 1.22 05/09/13 0.92 0.91 1.21 05/10/13 0.92 1.07 1.29 05/11/13 0.95 0.92 1.29 05/12/13 0.92 0.93 1.30 05/13/13 0.84 0.95 1.06 05/14/13 0.87 0.99 1.23 05/15/13 0.92 0.97 1.13 05/16/13 0.93 0.96 1.08 05/17/13 0.92 0.94 1.11 05/18/13 0.92 0.89 1.21 05/19/13 0.96 0.89 1.25 05/20/13 0.95 0.89 1.27 05/21/13 0.95 0.92 1.26 05/22/13 0.92 0.93 1.27 05/23/13 0.94 0.93 1.30 05/24/13 0.94 0.95 1.29 05/25/13 0.93 0.95 1.26 05/26/13 0.94 0.93 1.31 05/27/13 0.94 0.98 1.30 05/28/13 0.96 1.08 1.29 05/29/13 0.95 0.96 1.23 05/30/13 0.95 0.94 1.23 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 05/31/13 0.94 0.97 1.26 06/01/13 0.97 1.11 1.26 06/02/13 0.93 1.09 1.25 06/03/13 0.91 0.90 1.20 06/04/13 0.91 1.08 1.18 06/05/13 0.90 1.10 1.18 06/06/13 0.92 1.11 1.23 06/07/13 0.92 1.10 1.22 06/08/13 0.87 1.16 1.15 06/09/13 0.94 1.11 1.22 06/10/13 0.91 1.09 1.29 06/11/13 0.89 1.14 1.22 06/12/13 0.85 1.24 1.10 06/13/13 0.82 1.09 1.14 06/14/13 0.86 1.07 1.14 06/15/13 0.86 1.05 1.18 06/16/13 0.90 1.02 1.16 06/17/13 0.91 1.07 1.21 06/18/13 0.90 0.93 1.26 06/19/13 0.89 0.94 1.24 06/20/13 0.89 0.92 1.25 06/21/13 0.87 0.90 1.21 06/22/13 0.86 0.90 1.20 06/23/13 0.92 0.89 1.25 06/24/13 0.90 0.92 1.27 06/25/13 0.91 0.78 1.27 06/26/13 0.92 0.92 1.29 06/27/13 0.93 0.94 1.35 06/28/13 0.91 0.76 1.35 06/29/13 0.88 0.73 1.31 06/30/13 0.93 0.76 1.33 07/01/13 0.92 0.79 1.31 07/02/13 0.91 0.77 1.30 07/03/13 0.90 0.74 1.23 07/04/13 0.90 0.93 1.33 07/05/13 0.95 1.10 1.47 07/06/13 0.93 1.10 1.40 07/07/13 0.92 1.11 1.38 07/08/13 0.92 1.11 1.21 07/09/13 0.92 1.09 1.46 07/10/13 0.90 1.04 1.44 07/11/13 0.91 1.09 1.51 07/12/13 0.94 1.12 1.46 07/13/13 0.92 1.11 1.39 07/14/13 0.93 1.10 1.43 07/15/13 0.91 1.07 1.38 07/16/13 0.88 1.16 1.37 07/17/13 0.89 1.17 1.34 07/18/13 0.90 1.08 1.30 07/19/13 0.93 1.11 1.41 07/20/13 0.94 1.13 1.43 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 07/21/13 0.92 1.10 1.35 07/22/13 0.87 1.16 1.17 07/23/13 0.91 1.20 1.25 07/24/13 0.88 1.13 1.34 07/25/13 0.90 1.09 1.28 07/26/13 0.90 1.09 1.20 07/27/13 0.84 1.10 1.21 07/28/13 0.87 1.14 1.12 07/29/13 0.78 1.32 0.86 07/30/13 0.61 1.43 2.27 07/31/13 0.62 1.09 1.54 08/01/13 0.45 0.98 0.27 08/02/13 0.72 1.05 1.16 08/03/13 0.70 1.72 0.66 08/04/13 0.88 1.44 1.33 08/05/13 0.87 1.16 1.42 08/06/13 0.85 1.09 1.30 08/07/13 0.81 1.24 1.32 08/08/13 0.82 1.25 1.28 08/09/13 0.81 1.20 1.27 08/10/13 0.81 1.20 1.24 08/11/13 0.68 1.29 1.24 08/12/13 0.96 1.28 1.30 08/13/13 0.86 1.29 1.29 08/14/13 0.89 1.25 1.33 08/15/13 0.89 1.27 1.31 08/16/13 0.90 1.25 1.35 08/17/13 0.95 1.22 1.39 08/18/13 0.96 1.26 1.57 08/19/13 0.98 1.26 1.61 08/20/13 0.97 1.24 1.47 08/21/13 0.96 1.24 1.48 08/22/13 0.96 1.26 1.47 08/23/13 0.94 1.25 1.39 08/24/13 0.94 1.22 1.42 08/25/13 0.94 1.28 1.47 08/26/13 0.95 1.27 1.44 08/27/13 0.94 1.23 1.44 08/28/13 0.92 1.22 1.42 08/29/13 0.93 1.30 1.38 08/30/13 0.92 1.22 1.42 08/31/13 0.93 1.20 1.42 09/01/13 0.90 1.27 1.35 09/02/13 0.89 1.18 1.31 09/03/13 0.88 0.98 1.25 09/04/13 0.88 1.01 1.30 09/05/13 0.88 1.25 1.32 09/06/13 0.91 1.34 1.38 09/07/13 0.91 1.30 1.36 09/08/13 0.92 1.25 1.35 09/09/13 0.92 1.21 1.34 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 09/10/13 0.89 1.08 1.32 09/11/13 0.91 1.05 1.39 09/12/13 0.90 1.07 1.37 09/13/13 0.91 1.07 1.37 09/14/13 0.91 1.10 1.37 09/15/13 0.91 1.09 1.39 09/16/13 0.91 1.06 1.39 09/17/13 0.90 1.11 1.47 09/18/13 0.92 1.11 1.46 09/19/13 0.91 1.12 1.42 09/20/13 0.90 1.16 1.38 09/21/13 0.91 1.24 1.40 09/22/13 0.91 1.36 1.51 09/23/13 0.92 1.34 1.46 09/24/13 0.91 1.34 1.53 09/25/13 0.90 1.35 1.59 09/26/13 0.94 1.31 1.88 09/27/13 0.93 1.29 1.74 09/28/13 0.92 1.30 1.79 09/29/13 0.93 1.27 1.77 09/30/13 0.92 1.23 1.64 10/01/13 0.92 1.28 1.58 10/02/13 0.92 1.28 1.06 10/03/13 0.91 1.23 1.10 10/04/13 0.87 1.36 1.15 10/05/13 0.88 1.43 1.03 10/06/13 0.90 1.37 0.87 10/07/13 0.91 1.32 0.88 10/08/13 0.89 1.33 0.83 10/09/13 0.89 1.36 0.80 10/10/13 0.90 1.28 0.81 10/11/13 0.91 1.40 0.82 10/12/13 0.91 1.36 0.83 10/13/13 0.87 1.36 0.81 10/14/13 0.87 1.21 0.82 10/15/13 0.87 1.23 0.81 10/16/13 0.89 1.23 0.82 10/17/13 0.88 1.24 0.81 10/18/13 0.87 1.29 0.84 10/19/13 0.86 1.22 0.84 10/20/13 0.88 1.25 0.86 10/21/13 0.86 1.22 0.84 10/22/13 0.86 1.28 0.85 10/23/13 0.86 1.29 0.85 10/24/13 0.87 1.25 0.87 10/25/13 0.87 1.32 0.83 10/26/13 0.87 1.32 0.83 10/27/13 0.85 1.32 0.86 10/28/13 0.86 1.36 0.85 10/29/13 0.88 1.32 0.85 10/30/13 0.86 1.34 0.86 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 10/31/13 0.86 1.32 0.84 11/01/13 0.86 1.34 0.87 11/02/13 0.87 1.34 0.93 11/03/13 0.91 1.44 1.00 11/04/13 0.87 1.31 0.89 11/05/13 0.86 1.29 0.86 11/06/13 0.84 1.22 0.88 11/07/13 0.82 1.12 0.89 11/08/13 0.81 1.10 0.91 11/09/13 0.94 1.08 0.92 11/10/13 0.92 1.06 0.89 11/11/13 0.90 1.11 0.89 11/12/13 0.80 1.14 0.88 11/13/13 0.85 1.12 0.88 11/14/13 0.84 1.12 0.86 11/15/13 0.84 1.16 0.87 11/16/13 0.83 1.14 0.87 11/17/13 0.82 1.11 0.89 11/18/13 0.87 1.11 0.88 11/19/13 0.83 1.10 0.88 11/20/13 0.83 1.11 0.84 11/21/13 0.83 1.14 0.82 11/22/13 0.84 1.15 0.85 11/23/13 0.87 1.17 0.91 11/24/13 0.88 1.12 0.94 11/25/13 0.84 1.13 0.90 11/26/13 0.86 1.13 0.87 11/27/13 0.85 1.11 0.88 11/28/13 0.87 1.17 0.82 11/29/13 0.86 1.20 0.81 11/30/13 0.87 1.20 0.71 12/01/13 0.86 1.20 0.73 12/02/13 0.86 1.10 0.75 12/03/13 0.86 1.20 0.80 12/04/13 0.87 1.18 0.76 12/05/13 0.85 1.16 0.75 12/06/13 0.85 1.13 0.74 12/07/13 0.86 1.15 0.92 12/08/13 0.86 1.19 0.94 12/09/13 0.86 1.13 0.93 12/10/13 0.87 1.10 0.91 12/11/13 0.86 1.11 0.84 12/12/13 0.83 1.16 0.78 12/13/13 0.86 1.14 0.77 12/14/13 0.89 1.20 0.80 12/15/13 0.88 1.17 0.79 12/16/13 0.86 1.13 0.75 12/17/13 0.89 1.08 0.81 12/18/13 0.90 1.07 0.81 12/19/13 0.89 1.18 0.81 12/20/13 0.86 1.26 0.78 Exhibit 3-H 2013 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 12/21/13 0.86 1.32 0.78 12/22/13 0.85 1.34 0.78 12/23/13 0.88 1.32 0.77 12/24/13 0.86 1.43 0.78 12/25/13 0.85 1.49 0.77 12/26/13 0.87 1.46 0.78 12/27/13 0.87 1.48 0.80 12/28/13 0.88 1.47 0.82 12/29/13 0.88 1.48 0.82 12/30/13 0.86 1.24 0.80 12/31/13 0.92 1.27 0.85 Mean 0.90 1.12 1.14 Standard Deviation 0.059 0.181 0.232 Section 4 Sag River Oil Pool List of Exhibits Waterflood Pattern Map 4-A Total Reservoir Production Plot 4-B Total Reservoir Injection Plot 4-C Pertinent Data Summary 4-D Reservoir Voidage Balance 4-E Static Pressure Data 4-F Injection Rate & Pressure Data By Well 4-G Sag River Oil Pool Waterflood Project Summary The Sag River waterflood area is shown in Exhibit 4-A. The locations of production and injection well pairings are shown to give a general visualization of waterflood polygons, but do not show estimated waterflood sweep. 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. The locations of the active production and injection wells are shown with the waterflood pattern specifically identified. During 2013, there were two active Sag production wells (MPK-33 and MPC-23) and no active injection wells. Exhibit 4-B shows a production plot for the Sag River reservoir covering the entire history through December 2013. 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. The Sag River Oil Pool oil production averaged 299 STBD, gas production averaged 190 MSCFD, and water production averaged 1 STBD in 2013. Cumulative production through the end of 2013 is 2.55 MMSTB of oil, 2.60 BSCF of gas, and 2.40 MMSTB of water. In 2013, the average water cut dropped to 0%, a significant decrease over the 2012 average water cut of 50.2%. The drop in water cut was a result of shutting-in MPF-33A. In 2013, the average GOR was 636 SCF/STB, a decrease from the 2012 average GOR of 1014 SCF/STB. Exhibit 4-C shows an injection plot for the Sag River reservoir through December 2013. 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, 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 2013 remained the same as at the end of 2012 at 3.02 MMSTB and cumulative gas injection at the end of 2013 is 0.32 BSCF. MPC-23 is cycled to stay within GOR guidelines. Exhibit 4-D presents a summary of the pertinent production information for the Sag River Oil Pool. Exhibit 4-E shows a monthly breakdown of production and injection data for the report period. Exhibit 4-F presents the reservoir pressure data for the Sag River wells taken during 2013. 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, 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-G 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 2013. Milne Point Unit Boundary Milne Point Sag River PA Well Status: Producer online Injector shut in Producer shut in 1 1 2 mi 0 Area Map – Sag River Formation, Milne Point Field, 2013 Exhibit 4-B BP ALASKA - Milne Point Unit SAG Reservoir, Total Production 10 100 1000 10000 1 10 100 1000 10000 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 Gas Production (MMSCF, MSCF/DAY) Oil Production (MSTB, STB/DAY) Water Production (MSTB, STB/DAY) Oil Prod Cum SAG Oil Prod Rate SAG Water Prod Cum SAG Water Prod Rate SAG Gas Prod Rate SAG Gas Prod Cum SAG 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 10 11 12 13 GOR/1000Water Cut % / # Producers OnLineProducers OnLine Wtr Cut %Gas/Oil Ratio SAG 2013 Ex 2-4 B&C production_injection.xls 1/21/2014 Exhibit 4-C BP ALASKA - Milne Point Unit SAG Reservoir, Injection 10 100 1000 10000 10 510 1010 1510 2010 2510 3010 3510 4010 4510 02 03 04 05 06 07 08 09 10 11 12 13 Gas Injection MMSCF, (MSCF/DAY) Water Injection (MSTB, STB/DAY) Water Inj Cum SAG Water Inj Rate SAG Gas Inj Cum SAG Gas Inj Rate SAG 0 1 2 02 03 04 05 06 07 08 09 10 11 12 13# Injectors OnlineWater Injector OnLine Gas Injector OnLine 2013 Ex 2-4 B&C production_injection.xls 1/21/2014 Exhibit 4-D Exhibit 4-D Milne Point Unit - Sag River Oil Pool Milne Point Unit - Sag River Oil Pool SUMMARY OF PERTINENT DATA SUMMARY OF PERTINENT DATA 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)1,254 Gas (MMSCF)1,298 Water (MSTB)920 FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB)3,020 Injection Gas (MMSCF)324 AVERAGE OF PRESSURES OBTAINED IN 2013 @ 8,700' TVD ss December, 2013 Pressure (psig)3,797 WELL COUNT (Wells in Operation)* Production Wells 2 WAG Injection 0 Water Only Injection 1 Gas Only Injection 0 Notes: * Reflects ONLY operable wells. As of December 31, 2013 Exhibit 4-E Milne Point Unit Sag River Oil Pool 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 41274 (stb/day)(stb/day)(mscf/day)(rbbl/day)(stb/day)(mscf/day)(rbbl/day)Ratio (rbbl/day) 1/31/2013 239.0 0.0 171.0 354 0.0 0 0 0.00 -354 2/28/2013 246.0 0.0 135.0 344 0.0 0 0 0.00 -344 3/31/2013 250.0 0.0 97.0 350 0.0 0 0 ---350 4/30/2013 226.0 0.0 92.0 316 0.0 0 0 ---316 5/31/2013 206.0 0.0 84.0 288 0.0 0 0 0.00 -288 6/30/2013 216.0 0.0 43.0 302 0.0 0 0 0.00 -302 7/31/2013 210.0 0.0 23.0 294 0.0 0 0 0.00 -294 8/31/2013 216.0 0.0 25.0 302 0.0 0 0 0.00 -302 9/30/2013 236.0 0.0 28.0 330 0.0 0 0 0.00 -330 10/31/2013 273.0 12.0 359.0 532 0.0 0 0 0.00 -532 11/30/2013 518.0 0.0 558.0 899 0.0 0 0 0.00 -899 12/31/2013 753.0 0.0 666.0 1,205 0.0 0 0 0.00 -1,205 Average: 2013 299 1 190 460 0 0 0 0.00 -460 Cumulative:mstb mstb mmscf mrb mstb mmscf mrb mrb 31-Dec-13 2,553 2,401 2,600 6,776 3,020 324 3,309 0.49 -3,468 RESERVOIR VOIDAGE BALANCE January - December 2013 Page 1 Exhibit 4-F Static Pressure Data Sag River Oil Pool 6. Oil Gravity: API - 34 8. Well Name and Number: 9. API Number 50-XXX-XXXXX-XX-XX 10. Oil (O) or Gas (G) 11. AOGCC Pool Code 12. Final Test Date 13. Shut-In Time, Hours 14. Press. Surv. Type (see instructions for codes) 15. B.H. Temp.16. Depth Tool TVDss 17. Final Observed Pressure at Tool Depth 18. Datum TVDss (input)19. Pressure Gradient, psi/ft. 20. Pressure at Datum (cal) MPC-23 50-500-29226-43-00 PROD 525150 7/28/2013 40 PP 8,580 2,181 8,750 0.441 2,256 MPF-73A 50-500-29227-44-01 INJ 525150 5/28/2013 103922 SBHP 140 6,500 4,192 8,750 0.440 5,183 MPK-33 50-500-29227-29-00 PROD 525150 11/8/2013 25776 PP 155 6630 3020 8,750 0.440 3,953 Average 3,797 FL Fluid Level PBU Pressure Build Up PFO Pressure Fall Off PP Pump Pressure SBHP Shut-In Bottom Hole Pressure 3/28/2014Gerrit Verbeek Signature Printed Name Title Date STATE OF ALASKA 7. Gas Gravity: Air = .653. Unit or Lease Name: Milne Point RESERVOIR PRESSURE REPORT 4. Field and Pool: Sag River Oil Pool ALASKA OIL AND GAS CONSERVATION COMMISSION Resrevoir Engineer 21. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. 5. Datum Reference: 8750' SS 1. Operator: BPXA 2. Address: 900 E. Benson Blvd Anchorage, Alaska 99508-4254 Exhibit 4-G Milne Point Field Sag River Pool Sw Name Month Wellhead Pres Avg (psi) Days Operating Product Code Inj Vol Alloc (BBL, MCF) Injection Rate (BBL, MCF) MPF-73A 1/1/2013 0 H2O 0 MPF-73A 2/1/2013 0 H2O 0 MPF-73A 3/1/2013 0 H2O 0 MPF-73A 4/1/2013 0 H2O 0 MPF-73A 5/1/2013 0 H2O 0 MPF-73A 6/1/2013 0 H2O 0 MPF-73A 7/1/2013 0 H2O 0 MPF-73A 8/1/2013 0 H2O 0 MPF-73A 9/1/2013 0 H2O 0 MPF-73A 10/1/2013 0 H2O 0 MPF-73A 11/1/2013 0 H2O 0 MPF-73A 12/1/2013 0 H2O 0 Injection Rate and Pressure Data Section 5 Production/Injection Well Surveillance List of Exhibits Milne Point Surveillance 1/1/2013 – 12/31/2013 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 2013. Nine injection surveys were obtained in 2013. All of these injection surveys were performed in multi-zone injectors. There were 14 existing unregulated Schrader Bluff multi-zone injectors in 2013, four of which were shut in all year and one injector (MPG-05) which was only on injection for a total of 6 hours. Injection surveys were run in 3 of the 9 online unregulated Schrader Bluff multi-zone injectors, and in one regulated multiple zone injector, MPI-09. No injection survey was needed in the Sag River Oil Pool because no injectors were online during 2013. 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 or Schrader Bluff wells in 2013. In place of regular production logs, the Schrader Bluff field has utilized geochemical fingerprinting in the past, to determine production splits from the N, OA, and OB sands. In 2007 the geochemical fingerprinting program for the Schrader Bluff was suspended. In 2011 geochemical fingerprinting was initiated for MPI-12. This is the only well where geochemical fingerprinting is currently applied. Exhibit 5-A is a summary of the Milne Point field well surveillance performed in 2013 on both producers and injectors. Exhibit 5-A Milne Point Unit 2013 Surveillance Kuparuk River Oil Pool Schrader Bluff Oil Pool Sw Name Project Well Type Rec Date Log Type Comments MPC-03 MILNE_KUP PROD 4/26/2013 STP Splits: Gas Lift Survey, all gas entering GLM#1 MPC-07 MILNE_KUP PROD 6/23/2013 STP Splits: Gas Lift Survey, all gas entering GLM#3 MPC-15 MILNE_KUP INJ 7/6/2013 STP Splits: Bad Data MPC-25A MILNE_KUP INJ 7/6/2013 STP Splits: 38% C1, 10% LCU/B, 52% A2/A3 MPC-36 MILNE_KUP INJ 7/7/2013 STP Splits: Inconclusive, Bad Data MPF-62 MILNE_KUP INJ 7/10/2013 STP Splits: 16% A1, 12% A2, 72% A3, 0% B6 MPF-89 MILNE_KUP INJ 7/12/2013 STP Well was Shut-in, Base Line Temperature Log MPE-07 MILNE_KUP INJ 7/24/2013 STP Splits: 56% C1, 44% B MPF-95 MILNE_KUP INJ 8/29/2013 STP Splits: Inconclusive, Bad Data MPC-06 MILNE_KUP INJ 9/18/2013 STP Splits: Inconclusive, Bad Data MPC-10 MILNE_KUP INJ 9/18/2013 STP Splits: 32% B&C (Straddle), 68% A MPC-19 MILNE_KUP INJ 9/19/2013 STP Splits: 100% A3 MPI-09 MILNE_SCHRADER INJ 6/24/2013 STP Splits: 40% NB, 12% OA, 48% OB MPG-13 MILNE_SCHRADER INJ 8/30/2013 STP Splits: 100% OA MPS-15 MILNE_SCHRADER INJ 9/20/2013 STP Splits: 100% OB MPJ-15 MILNE_SCHRADER INJ 9/29/2013 STP Splits: 100% OA MPI-12 MILNE_SCHRADER PROD 1/3/2013 GEO Splits: 28% OA, 72% OB V. Good MPI-12 MILNE_SCHRADER PROD 4/22/2013 GEO Splits: 32% OA, 68% OB Good MPI-12 MILNE_SCHRADER PROD 6/11/2013 GEO Splits: 32% OA, 68% OB Good MPI-12 MILNE_SCHRADER PROD 10/22/2013 GEO Splits: 17% OA, 83% OB Good DED = RFT =Repeated Formation Test FSPL =RST =Reservior Saturation Tool GEO = SZT =Separate Zone Test Dedicated injection into single sand Full Suite Production Log Geochemical Analysis of Production splits Section 6 Shut in Well Status List of Exhibits Milne Point Shut in Well Status 1/1/2013 – 12/31/2013 6-A Exhibit 6-A 2013 Shut-In Wells Milne Point Unit Sw Name Reservoir Reason for Well Shut- In1 Current Mechanical Condition of Well, including integrity issues2 Future Utility Plans & Possibilities3 Comments MPB-01 Kuparuk E ESP failed 3 Water source well not currently needed. Evaluate replacing ESP when need arises. MPB-03 Kuparuk A Currently has TxIA communication through broken GLV in GLM#1. 3 Although well has TxIA communication, WELLS has suggested that it could still 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-06 Kuparuk D Surface casing leak.3 Cost is approximately. $4MM for a SC repair. Not economic on a ~100 bopd well. MPB-07 Kuparuk 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. Diagnostics determined potential source of pressure from packer leak. Well has been secured. Well will have reservoir P&A. MPB-08i Kuparuk E 4 Well does not support any producers. No flowlines or wellhouse. MPB-11i Kuparuk D Tubing leak; well secured with sand plug.1 Need to fix leaking permanent patch and perform FCO. MPB-12i Kuparuk E No known problems.6 Well supports MPB-03. If MPB-03 ever comes back online, then B-12i will be brought BOI to support it. MPB-13 Kuparuk B 1 No wellhouse, flowlines or slot in module. Plan to convert to water injector. 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 injection. No current plans to bring the well BOI. MPB-17i Kuparuk E No mechanical problems.3 Wellhouse and flowlines removed. Quick communication with producer. Evaluate potential sidetrack. MPB-19 Kuparuk B No known problems.3 Wellhouse and flowlines removed. GL well. High water cut producer. Possible frac into water zone. Evaluate potential sidetrack. MPB-23 Kuparuk A Cement Packer Squeeze repaired the TxIA communcation in May 2012. 6 Producer is in the same HU as gas injector E-03. Well comes online with very high GOR. Will likely be used for gas flowbacks if Milne encounters a gas shortage for fuel gas. MPB-25i Kuparuk E No known problems.6 Ready to turn 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&A'd due to subsurface subsidence damage. MPC-05A Kuparuk E RWO on schedule to fix TxIA communication.6 RWO SOR has been signed and well is currently on Rig schedule to have tubing replaced. MPC-08i Kuparuk E Offset to S/I MPL-06, high BHP 6 Return to water injection when BHP is reduced, may try bringing BOI to support MPC- 09. MPC-09 Kuparuk E RWO fixed SC leak in February 2014.6 Plan to bring back on production once post-rig work is completed. MPC-11i 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 cement plugs with EZSV retainers over perfs. 4 High GOR from E-03 gas breakthrough. MPC-17i Kuparuk D Leak in 9 5/8" casing to surface 6 scoping out non-rig remedial actions MPC-20 Kuparuk B No wellhouse, no flow lines 3 High water cut. Perf'd without good logs. Wellhouse and flowlines removed. Would need WSO. MPC-41 Schrader A No Issues 1 Pursuing conversion to injector. MPCFP-02i Kuparuk E No known mechanical problems 3 Thief zone directly to offset producers. Evaluate Sag/Schrader potential. MPD-01 Kuparuk C Dead ESP completion downhole, no support to block 5 No support to block. No flowlines from D pad. Plan to P&A in the future. MPD-02A Kuparuk B Well has TxIA communication. Well resecured post SBHP April - 2008 with downhole plug. 5 High water cut 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 Kuparuk E Long term shut in 1 MPE-16 supports MPB-06 which is shut-in for surface casing leak. MPE-16 will remain shut-in until B-06 comes back on line. MPE-18 Kuparuk D 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 7/28/2012 4 Severe casing buckling 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 connectivity. MPF-33A Sag River D Stuck jet pump 2 S/I due to stuck jet pump. RWO planned in 2014 MPF-41i Kuparuk E S/I for pressure management 6 Drilled as a producer. High water saturation so converted to injection. No response seen in offset producer. Evaluate potential sidetrack. MPF-49i Kuparuk E S/I for pressure management 6 S/I for pressure management MPF-73Ai Sag River E S/I for pressure management 6 Plan to POI in 2014 post MPF-33A's RWO. MPF-80 Kuparuk E Suspended well June 2011. Well plugged 4 Suspended well June 2011 MPF-83i Kuparuk E No known problems 3 Injection support not seen in offset producers MPF-86 Kuparuk E Awaiting POP post sand consolidation treatment 6 Plan to POP in 2014 MPF-90i Kuparuk C No producer connections 1 S/I for lack of producer connections MPG-04 Schrader C ESP failed 3 MPG-08A Schrader C ESP failed 1 High sand production. Intervention under evaluation. MPG-11 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 Ugnu 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-09 Schrader D Suspended, Hole in casing at 311'5 P&A in progress. MPH-10 Schrader D ESP failed, Hole in casing 3 MPH-11i 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 damage 5 Solids production from breached screen, MBE with injector. Shallow subsidence MPI-01 Schrader C ESP failed 3 Flowline removed in '98. Solids producer. Bottom hole location replaced by I-15. 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-13LSi Schrader B No known problems 2 High pressure in offset SI producer MPI-13SSi Schrader B No known problems 6 High pressure in southern offset SI producer. Will put back online with Northern offset producer MPI-15 Schrader C ESP failed 1 Need additional injection support MPJ-04 Schrader C ESP failed 1 Low flow, considering for sidetrack MPJ-07 Schrader D ESP failed; TxIAxOA 3 Bottom hole location replaced by H-18 MPJ-12 Kuparuk C ESP failed 1 No surface facilities. Evaluate potential sidetrack targets. MPJ-16i Kuparuk E No known problems 1 No surface facilities. Evaluate potential sidetrack targets. MPJ-20Ai 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 MPJ-26 Schrader C ESP Failed 2 RWO planned MPK-05 Kuparuk C ESP failed 1 Well returned to service via RWO. MPK-09 Kuparuk C ESP failed 1 Needs RWO to replace failed ESP MPK-13 Kuparuk C ESP failed 1 Needs RWO to replace failed ESP MPK-18Ai Kuparuk E Corrosion from source water 1 RWO to replace tubing is uneconomic. MPK-30 Kuparuk C ESP failed 1 Well returned to service via RWO. MPK-34 Ugnu E No integrity issues 1 Water Source Well. Back in service. MPK-37 Kuparuk D Needs RWO to replace failed ESP 1 RWO planned for 2014. MPK-38 Kuparuk D Needs RWO to replace failed ESP 1 RWO planned for 2014. MPK-43Ai Kuparuk D Corrosion from source water - needs RWO.1 RWO planned for 2014. MPL-01A Kuparuk D ESP failed.1 Intervention under evaluation *Note - wells were shut-in 100% in 2013 Exhibit 6-A 2013 Shut-In Wells Milne Point Unit MPL-06 Kuparuk D Reservoir section abandoned 4 Well suspended during 5/2012 RWO. Reservoir section abandoned. MPL-10i Kuparuk E No known mechanical problems 1 Intervention under evaluation MPL-17 Kuparuk D ESP failed. Low remaining reserves 1 Low remaining reserves. Evaluate potential gas storage well or Kuparuk sidetrack. MPL-21i Kuparuk E High pressure block. 1 Intervention under evaluation MPL-34i Kuparuk E Suspended 12/1/2008. High pressure block. 4 No indication of communicating with surrounding producers. MPL-37A Schrader C Dead ESP, no other mechanical issues 1 Planned sidetrack for NW Schrader development MPL-39i Kuparuk E No known mechanical problems 2 No surface facilities. Located in isolated fault block, does not support offset producers. Plan to convert to producer. MPL-42i Kuparuk D Slow TxIA communication on gas injection 1 Intervention under evaluation MPL-45 Schrader C ESP failed. 1 Low productivity. Evaluate conversion to jet pump or potential Schrader sidetrack. MPS-01BLSi Schrader D No integrity issues 3 Injector has MBE MPS-01BSSi 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-06i Schrader E No integrity issues 6 No offtake in 2012, plan to return to injection when offset producers are online MPS-07LSi Schrader D Suspended 11/17/2011. Surface casing leak 4 Suspended Nov. 2011 MPS-07SSi Schrader D Suspended 11/17/2011. Surface casing leak 4 Suspended Nov. 2011 MPS-09LSi Schrader D Surface casing Issue 3 MPS-09SSi Schrader D Surface casing Issue 3 MPS-10ALSi Schrader D Operable with String communication 3 Intervention under evaluation MPS-10ASSi Schrader D Operable with String communication 3 Intervention under evaluation MPS-13LSi Schrader D Annular communication 2 Intervention planned MPS-13SSi Schrader D Annular communication 1 Intervention under evaluation MPS-21i Schrader E No known problems, Cement over perforations 1 Lost CT under-reamer in hole MPS-22 Ugnu C No known problems 1 Low PI. MPS-27 Schrader D Integrity concerns 1 No issues but SI for uncertainty about integrity of the well MPS-29 Schrader E Fill in wellbore 6 Lack of injection support due to MBE's MPS-32 Schrader D Casing leak 1 Intervention under evaluation MPS-33ASSi Schrader E No integrity issues 1 MBE to producer, potential MBE treatment candidate MPS-37 Ugnu D Pump problem.3 Long term shut in well. MPS-41A Ugnu D Suspended with cement.4 Unable to fish tubing. Reasons for Well Shut-In 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 including 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 term Shut-in well/No immediate plans 4. Suspended well 5. P&A planned 6. Other (Specify under comments) *Note - wells were shut-in 100% in 2013 Section 7 Milne Point Well Testing with ASRC Unit 5 and Weatherford Gen 2 (VSRD) Summary List of Exhibits Well Test Frequency 7-A VSRD Well Test Plots G-Pad Plot 7-B S-Pad Plot 7-C Milne Point Well Testing Milne Point primarily utilizes on-pad separators for well testing. The pad separators at B, 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 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 2013. 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 BP 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 2013 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, Figure 7-B shows the repeatability and reliability of the metered rates, as well as, the test frequency of a typical G-Pad well during the entire 2013 year. 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. Currently all B-Pad production is allocated from the portable ASRC test separator. 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 ±10% and water cut with an uncertainty band of ±2.5 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 3-H (Schrader Bluff Oil Pool) provides daily oil, gas, and water allocation factors for the Milne Point Facility for 2013. Exhibit 7-A 2013 Well Testing Milne Point Unit 2013 Average Tests / Month * Field total all 6.9 KUP all 6.1 SBF all 8.7 SAG all 10.3 Reservoir Pad KUP B 0.2 KUP C 8.9 KUP E 5.2 KUP F 4.4 KUP H 6.2 KUP J 6.9 KUP K 13.2 KUP L 8.9 SBF C 0.0 SBF E 6.3 SBF G 18.3 SBF H 5.0 SBF I 7.5 SBF J 7.8 SBF S 9.1 SAG C 7.4 SAG F 0.0 SAG K 29.9 * Average Tests / Month calculated as total number of tests divided by days operating divided by 30.5 days per month. Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month * MPB MPB-04A KUP 1 244 3 0.4 MPB MPB-09 KUP 1 348 2 0.2 MPB MPB-10 KUP 1 345 2 0.2 MPB MPB-15 KUP 1 348 2 0.2 MPB MPB-16 KUP 1 334 2 0.2 MPB MPB-21 KUP 1 352 2 0.2 MPB MPB-22A KUP 1 353 2 0.2 MPC MPC-01 KUP 1 196 40 6.2 MPC MPC-03 KUP 1 354 130 11.2 MPC MPC-04 KUP 1 345 118 10.4 Exhibit 7-A 2013 Well Testing Milne Point Unit Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month * MPC MPC-07 KUP 1 356 121 10.4 MPC MPC-13 KUP 1 360 99 8.4 MPC MPC-14 KUP 1 271 70 7.9 MPC MPC-21 KUP 1 341 99 8.9 MPC MPC-22A KUP 1 361 109 9.2 MPC MPC-23 SAG 2 349 85 7.4 MPC MPC-24A KUP 1 282 83 9.0 MPC MPC-26 KUP 1 351 89 7.7 MPC MPC-40 KUP 1 341 88 7.9 MPC MPC-43 KUP 1 359 95 8.1 MPE MPE-04 KUP 1 361 75 6.3 MPE MPE-06 KUP 1 361 65 5.5 MPE MPE-09 KUP 1 359 62 5.3 MPE MPE-10 KUP 1 293 40 4.2 MPE MPE-11 KUP 1 212 25 3.6 MPE MPE-14A KUP 1 357 58 5.0 MPE MPE-15 SBF 2 322 57 5.4 MPE MPE-19 KUP 1 194 32 5.0 MPE MPE-20A SBF 2 292 55 5.7 MPE MPE-22 KUP 1 360 71 6.0 MPE MPE-24A SBF 2 200 58 8.8 MPE MPE-31 SBF 2 358 73 6.2 MPE MPE-32 SBF 2 361 72 6.1 MPF MPF-01 KUP 1 350 49 4.3 MPF MPF-05 KUP 1 358 54 4.6 MPF MPF-06 KUP 1 358 55 4.7 MPF MPF-09 KUP 1 358 57 4.9 MPF MPF-14 KUP 1 357 52 4.4 MPF MPF-18 KUP 1 356 57 4.9 MPF MPF-22 KUP 1 352 53 4.6 MPF MPF-25 KUP 1 309 47 4.6 MPF MPF-29 KUP 1 358 53 4.5 MPF MPF-34 KUP 1 357 57 4.9 MPF MPF-37 KUP 1 358 53 4.5 MPF MPF-38 KUP 1 358 54 4.6 MPF MPF-45 KUP 1 357 54 4.6 MPF MPF-50 KUP 1 261 35 4.1 MPF MPF-53 KUP 1 234 39 5.1 MPF MPF-54 KUP 1 358 57 4.9 MPF MPF-57A KUP 1 119 10 2.6 MPF MPF-61 KUP 1 358 50 4.3 MPF MPF-65 KUP 1 348 54 4.7 Exhibit 7-A 2013 Well Testing Milne Point Unit Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month * MPF MPF-66A KUP 1 358 45 3.8 MPF MPF-69 KUP 1 26 4 4.8 MPF MPF-78 KUP 1 274 36 4.0 MPF MPF-79 KUP 1 356 53 4.5 MPF MPF-81 KUP 1 351 44 3.8 MPF MPF-87A KUP 1 356 49 4.2 MPF MPF-93 KUP 1 78 10 3.9 MPF MPF-94 KUP 1 268 37 4.2 MPF MPF-96 KUP 1 279 21 2.3 MPG MPG-02 SBF 2 274 158 17.6 MPG MPG-14 SBF 2 315 209 20.2 MPG MPG-15 SBF 2 317 206 19.8 MPG MPG-16 SBF 2 154 72 14.3 MPG MPG-18 SBF 2 111 57 15.7 MPH MPH-05 KUP 1 352 71 6.1 MPH MPH-07A SBF 2 94 13 4.2 MPH MPH-08B SBF 2 327 63 5.9 MPH MPH-10 SBF 2 0 0 0.0 MPH MPH-16 SBF 2 202 36 5.4 MPH MPH-18 SBF 2 348 52 4.6 MPH MPH-19 SBF 2 270 41 4.6 MPI MPI-03 SBF 2 263 62 7.2 MPI MPI-04A SBF 2 0 0 0.0 MPI MPI-07 SBF 2 240 48 6.1 MPI MPI-12 SBF 2 289 91 9.6 MPI MPI-14 SBF 2 361 89 7.5 MPI MPI-17 SBF 2 361 96 8.1 MPI MPI-19 SBF 2 304 60 6.0 MPJ MPJ-01A SBF 2 345 91 8.0 MPJ MPJ-03 SBF 2 261 65 7.6 MPJ MPJ-05 SBF 2 7 1 4.2 MPJ MPJ-06 KUP 1 360 93 7.9 MPJ MPJ-08A SBF 2 296 86 8.9 MPJ MPJ-09A SBF 2 232 57 7.5 MPJ MPJ-10 KUP 1 295 55 5.7 MPJ MPJ-25 SBF 2 273 60 6.7 MPK MPK-02 KUP 1 304 104 10.4 MPK MPK-06 KUP 1 358 189 16.1 MPK MPK-17 KUP 1 358 147 12.5 Exhibit 7-A 2013 Well Testing Milne Point Unit Pad Well Formation Required Tests/ Month Days On Prod. Total Tests Average Tests / Month * MPK MPK-33 SAG 2 52 51 30.1 MPL MPL-02A KUP 1 65 15 7.0 MPL MPL-03 KUP 1 360 113 9.6 MPL MPL-04 KUP 1 177 44 7.6 MPL MPL-05 KUP 1 359 110 9.3 MPL MPL-07 KUP 1 361 120 10.1 MPL MPL-11 KUP 1 360 114 9.7 MPL MPL-12 KUP 1 328 98 9.1 MPL MPL-13 KUP 1 223 47 6.4 MPL MPL-14 KUP 1 328 101 9.4 MPL MPL-20 KUP 1 312 89 8.7 MPL MPL-25 KUP 1 149 37 7.6 MPL MPL-28A KUP 1 360 111 9.4 MPL MPL-29 KUP 1 338 98 8.8 MPL MPL-36 KUP 1 358 101 8.6 MPL MPL-40 KUP 1 360 104 8.8 MPL MPL-43 KUP 1 175 40 7.0 MPS MPS-05 SBF 2 22 15 20.7 MPS MPS-08 SBF 2 33 4 3.7 MPS MPS-12 SBF 2 347 73 6.4 MPS MPS-17 SBF 2 246 81 10.1 MPS MPS-19A SBF 2 222 69 9.5 MPS MPS-23 SBF 2 316 112 10.8 MPS MPS-24 SBF 2 0 0 0.0 MPS MPS-25 SBF 2 309 103 10.2 MPS MPS-28 SBF 2 356 112 9.6 MPS MPS-34 SBF 2 95 22 7.1 MPS MPS-35 SBF 2 294 76 7.9 Figure 7-B MPG-02 VSRD Well Tests 0 50 100 150 200 250 300 350 400 01/01/201302/20/201304/11/201305/31/201307/20/201309/08/201310/28/201312/17/201302/05/2014Oil Rate, bopd OilRate NOT APPROVED APPROVED PORTABLE 0.0 10.0 20.0 30.0 40.0 50.0 60.0 70.0 80.0 90.0 100.0 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 02/05/2014Watercut, % WaterCut NOT APPROVED APPROVED PORTABLE 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 02/05/2014GOR Liquid Density GOR NOT APPROVEDAPPROVED PORTABLE 0 200 400 600 800 1000 1200 1400 1600 1800 2000 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 02/05/2014BHP, psi BHFP NOT APPROVED APPROVED PORTABLE 0 50 100 150 200 250 300 350 400 01/01/2013 04/11/2013 07/20/2013 10/28/2013 02/05/2014Fluid Rate, bpd GrossFluid NOT APPROVEDAPPROVED PORTABLE 0 100 200 300 400 500 600 700 800 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 02/05/2014Gas Rate, mscfd GasRate NOT APPROVED APPROVED PORTABLE Figure 7-C MPS-28 VSRD Well Tests 0 100 200 300 400 500 600 700 800 900 1000 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 OilRate NOT APPROVED APPROVED PORTABLE Red Eye Maint. 0 10 20 30 40 50 60 70 80 90 100 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 WaterCut NOT APPROVED APPROVED PORTABLE Red Eye Maint. 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 GOR NOT APPROVED APPROVED PORTABLE Red Eye Maint. 0 200 400 600 800 1000 1200 1400 1600 1800 2000 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 BHFP NOT APPROVED APPROVED PORTABLE Red Eye Maint. 0 200 400 600 800 1000 1200 1400 1600 1800 2000 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 GrossFluid NOT APPROVED APPROVED PORTABLE Red Eye Maint. 0 50 100 150 200 250 300 350 400 450 500 01/01/2013 02/20/2013 04/11/2013 05/31/2013 07/20/2013 09/08/2013 10/28/2013 12/17/2013 GasRate NOT APPROVED APPROVED PORTABLE Red Eye Maint.