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2009 Milne Point Unit
Date: 03/31/2010 Attn: AOGCC Rcce1116 f1A R ,? r tfilf! ·Qr~~ BPXA Well DATA TRANSMITTAL Enclosed is the 2009 Waterflood Report for Milne Point, Surveillance Report and Shut in Well Report. (3 each: Hardcopy/CD ROM) Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool If you have any questions or concerns, please contact James Johnson, Data Manager BP Exploration at (907) 564-4173 or by emailing to johnsojh@bp.com . ~Ak~ Pl0S¥ s'(gn and Return one copy of this transmittal. Thank you, James H. Johnson ACT Data Manager bp David J. Szabo Head of Resource Management Alas ka Consolidated Team (ACT) March 31, 2010 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 W. ?'h Ave# 100 Anchorage, AK 99501-3539 BP Exploration {Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage , Alaska 995 19-6612 (907) 561-5111 Phone : (907) 564-4788 Fax : (907) 564-4440 Email SzaboDJ @bp .com Web : www .bp .com RE: Milne Point Unit Waterflood Report, Surveillance Report, and Shut in Well Report Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool Dear Mr. Seamount: In accordance with the requirements of Conservation Orders 205 and 432B (Kuparuk River Oil Pool), Conservation Order 477 (Schrader Bluff Oil Pool), and Conservation Order 423 (Sag River Oil Pool), the Operator of the Milne Point Unit hereby submits the consolidated Waterflood Surveillance Report for the Kuparuk River Oil Pool, the Schrader Bluff Oil Pool, and Sag River Oil Pool. This report covers the time period January 1 through December 31, 2009. This report also contains a list of the wells at Milne Point that have been shut in for 365 days in 2009 . This information is being provided in compliance with AOGCC regulation , 20 AAC 25.115 (Shut-in Wells). Due to the possible future plans for these wells it is our intent to leave the vast majority of them shut-in at this time and not to proceed with suspension or abandonment with the exception of those for which there is no future use. This report also contains a summary of performance and operational issues relating to the ASRC Unit 5 Multi Phase Flow Meter. This information is being provided in compliance with Conservation Order 550.007 (Administrative Approval for Unit 5 MPFM). The Operator of the Milne Point Unit reserves the right to alter the content of the analyses contained in this report at any time, based on the most recent surveillance information. s~~J;:Jf David Szabo ~ cc: Kevin Banks, DNR R. L. Skillern MPU File Milne Point Unit W aterflood and Reservoir Surveillance Report for Kuparuk River Oil Pool Schrader Bluff Oil Pool Sag River Oil Pool January through December, 2009 Issued: March 31, 2010 Sections and Exhibits Introduction Overview 1 Section 1: General Information Exhibits lA-lE 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-31 Sag River Oil Pool 4 Section 4: Sag River Oil Pool Exhibits 4A-4G Production/Injection Surveillance Logs 5 Section S: Production/Injection Well Surveillance Exhibits SA 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 7A ANNUAL RESERVOIR SURVEILLANCE REPORTS MILNE POINT UNIT KUPARUK RIVER OIL POOL SCHRADER BLUFF OIL POOL SAG RIVER OIL POOL JANUARY -DECEMBER 2009 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, 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 2009. 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. A separate Plan of Development is sent annually by October 1. 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. Each of the three producing reservoirs is reported in a separate section. Milne Point Unit Map Section 1 General Information List of Exhibits Overview Statistical Summary Kuparuk Pressure Map Schrader Bluff Pressure Map Sag River Pressure Map 1-A 1-B 1-C 1-D 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 (MW AG) 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), has been in effect and will continue to be implemented in the Milne Point Kuparuk reservoir. 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. In May 2005, injection at L pad was converted from produced water injection to lower salinity Prince Creek source water injection as a means of potentially increasing recovery. Observation of resulting production and salinity trends has indicated a clear chemical, but indistinct production response. Bright Water™ is a polymer additive to injection water that alters sweep patterns within the reservoir with the purpose of improving oil recovery. A Bright Water™ trial was pumped in MPB-12i in 2004 and monitoring of this injection pattern continued through 2005-06. The 2004 treatment yielded a positive response. A second Bright Water™ program was deployed in 2007 in which MPE-23i and MPF-62i were treated. Results from the 2007 program are unclear due to metering issues. In 2009, an injection header Bright Water treatment was pumped at MPC-Pad, in which five wells were simultaneously treated (MPC-02i, 06i, lOi, 15i, 19i). Responses from the 2009 program are expected in mid-late 2010. A drilling campaign was initiated in December 2008, commencing in March 2009, in which two coiled tubing sidetracks (MPB-22A, MPC-43) and one rotary well (MPF-96) were brought online. A second drilling campaign kicked off in December 2009 continuing through March 2010. Since none of these wells were online in 2009, they will not be included in the 2010 W aterflood Report. 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 2009, field production averaged 28.9 MBOD, 19.7 MMSCFD (GOR 681 SCF/STB) and 74.2 MBWD (water cut 72%). Waterflood injection during this period averaged 98.1 MBWD with 9.7 MMSCFD of gas injection. The overall field voidage replacement ratio was 0.89 RB/RB for 2009. As of December 31, 2009, cumulative water injection in the Kuparuk River Oil Pool was 404.6 MMSTB, while cumulative gas injection was 98.7 BSCF. Cumulative production was 220.9 MMSTB oil, 119.2 BSCF gas, and 232.9 MMSTB water. From first production to December 31, 2009, cumulative production exceeded injection by 45.4 MMRB. As of December 31, 2009, cumulative water injection in the Schrader Bluff Oil Pool was 115.0 MMSTB and cumulative gas injection in the Schrader Bluff Oil Pool was 220 MMSCF. Cumulative production was 60.9 MMSTB oil, 38.1 BSCF gas, and 42.1 MMSTB water. From first production to December 31, 2009, cumulative production has exceeded injection by 33 .6 MMRB. Cumulative water injection in the Sag River Oil Pool from startup through December 2009 was 2.0 MMSTB, while cumulative gas injection was 324 MMSCF. Cumulative production was 2.0 MMSTB oil, 2.0 BSCF gas, and 1.9 MMSTB water. As of December 31, 2009, cumulative production exceeded injection by 3.0 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. bp (?; - . . " . . - Exhibit 1-A Milne Point Unit Boundary and Kuparuk, Schrader Bluff and Sag River PAs, 2009 . . . -. . I - 0 8,000 16,000 32,000 Feet I I I I I I I I I -. - I I I I ·-··-·-· -· --. Legend ... ... -... L ... _J Milne Point Unit Bdry ·~ '1 .......... . i. ......... i Milne Pt SagR PA § Milne Pt Kuparuk PA -,_ ,----.., i Milne Pt Schrader PA . .. --. .. . ! - r==I . ., . . . -·: I i . l -I --:: I -· .. ~ . .. I ~--·· ! ~ ' i_· . ----· i i ~ : .. -,-···-···-i·Jl-··---··r .. ·-···-r··-··.,-·· I Exhibit 1-8 Milne Point Unit 2009 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS As of 12/31 /2008 Producers Injectors -WAG -Water Only -Gas Only As of 12/31/2009 Producers Injectors -WAG -Water Only -Gas Only Production Well Status in 2009 -Newly Drilled -Sidetracked or Redrilled Gas Injection Well Status in 2009 -Newly Drilled -Sidetracked or Redrilled WAG Injection Well Status in 2009 -Newly Drilled -Sidetracked or Redrilled Water Injection Well Status in 2009 -Newly Drilled -Sidetracked or Redrilled NOTES: Kuparuk Schrader River Bluff Oil Pool Oil Pool 90 58 53 44 40 2 12 42 1 0 88 54 48 42 24 0 23 42 1 0 0 0 0 0 1 0 2 0 0 0 0 0 0 0 0 0 (1) Well count reflects ONLY those wells that were operating at the time of interest. Sag River Oil Pool 1 1 0 1 0 2 1 0 1 0 0 0 0 0 0 0 0 0 Exhibit 1-B (continued) Milne Point Unit 2009 OVERVIEW STATISTICAL SUMMARY PRODUCTION/INJECTION STATISTICS Cumulative Production Through 12/31/2009 Oil (MSTB) Gas (MMSCF) Water (MSTB) Cumulative Injection Through 12/31/2009 Water (MSTB) Gas (MMSCF) Cumulative Voidage Balance Through 12/31/2009 Cum . Product ion (MRB) Cum. Injection (MRB) Over/Under (MRB) AVERAGE RATE 2009 Production: Oil (MBD) Gas (MMSCFD) Water (MBD) Injection: Water (MBD) Gas (MMSCFD) AVERAGE OF PRESSURES OBTAINED IN 2009 (psig) -December 2009 Kuparuk River Oil Pool 220 ,853 119 ,224 232 ,937 404 ,631 98 ,732 553 ,629 508 ,207 -45,421 19.5 15.1 56 .9 60 .9 9 .7 2 ,808 Schrader Sag Bluff River Oil Pool Oil Pool 60 ,941 2 ,039 38 ,093 2,028 42 , 113 1,855 115 ,000 2,022 220 324 150 ,126 5,290 116 ,503 2,281 -33 ,623 -3 ,008 9 .1 0 .39 4 .3 0 .24 17 .0 0 .23 36 .3 0.94 0 .0 0.00 1 ,522 3 ,969 bp 009 Kup A'esssure 1000 1500 2500 3000 3600 '4000 4500 5000 5500 Exhibit 1-C Milne Point Unit Note: All pressures were taken in 2009, where multiple pressures in a well, the one with longest shut-in period is used. w el statu's i + A~NDONED I . I . Ft\Jooeo BA CK FOR REDRIL~ I I ' ·-·-·-·-·~! -·-·-·-·-· Exhibit 1-D 2009 Schrader Bluff Formation Pressure Map Milne Point Unit N 2009 SBF Pressure 1000 • Prod 1 0 1 2 mi r-;---·· I lnj Note: Not all wells penetrate all sands, many are only in "N" sands or ·o ~ sands bp Sag Pressures t()()O 1500 2000 2500 3000 3500 4000 4500 5000 5500 Exhibit 1-E 2009 Sag River Formation Pressure Map Milne Point Unit . ,._ .. _ ... . ,._J . ,._J • ....... . ~--i I ' I -·-. I . ! I ,, -·-·-· -·-·-·!~ I i 111!1'11•-~-·-·--· -· .. Sl ~P32·14. I N I ··-·-·-·,..·-·-·-· • I I I • ·-·-~ I . I . I ··-·-·-·- MF'Lf 1 • I I 1 I o Fl FH Fl -·· . i I ! ·-·r -·-·L ...... PJ t l ·-·~·--·· Q. ~MPCw01·' I 1 2 mi ! I . ··-·· . '·-· !: i: ··-·"' I L, ___ , .. , t MP19·01 _: + ' 1--I ---ii I MPE i 13A • Waterflood Pattern Map Section 2 Kuparuk River Oil Pool List of Exhibits Total Reservoir Production Plot Total Reservoir Injection Plot Pertinent Data Summary Reservoir Voidage Balance Static Pressure Data Injection Rate & Pressure Data By Well 2-A 2-B 2-C 2-D 2-E 2-F 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 production and injection well pairings are shown to give a general visualization of waterflood polygons, but do not show estimated waterflood sweep. There were 88 producing wells and 48 injection wells active through 2009. Exhibit 2-B shows a production plot for the Kuparuk River reservoir covering the entire project history through December 2009. The Kuparuk River Oil Pool oil production averaged 19.5 MSTBD for 2009 compared to 20.1 MSTBD in 2008. This represents an oil production decrease of 3.1 % in 2009. Water production averaged 56.9 MBWD in 2009 and 58.2 MBWD in 2008, a decrease of 2.2%. Cumulative production since waterflood startup through the end of 2009 is 220.9 MMSTB of oil, 119.2 BSCF gas, and 232.9 MMSTB of water. Exhibit 2-C shows an injection plot for the Kuparuk River reservoir covering the entire project history through December 2009. Water and gas injection rates averaged 60.9 MBWD and 9.7 MMSCFD for 2009. Injection rates in 2008 averaged 61.1 MBWD and 10.2 MMSCFD. This represents a decrease in water injection of 0.2% and a decrease in gas injection of 4.6%. Cumulative water injection since waterflood startup through the end of 2009 is 404.6 MMSTB and cumulative gas injection is 98.7 BSCF. Average water cut increased from 74.3% in 2008 to 74.5% in 2009. Water cut continues to increase in the Kuparuk River reservoir as the waterflood patterns mature. Average GOR increased from 676 SCF/STB in 2008 to 775 SCF/STB in 2009. This GOR increase resulted from improvements to the gas handling system uptime enabling higher GOR wells to remain on production. 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 0.79 RB/RB in 2009. The VRR in 2008 averaged 0.80 RB/RB. This represents a decrease of 1.25%. The cumulative VRR for the reservoir is 0.92 RB/RB. The reservoir voidage calculation does not include the water influx from the aquifer, so the under-injection volume is overstated in this report. Exhibit 2-F presents the reservoir pressure data taken during 2009 for the Kuparuk River wells . In 2009, 97 pressures were obtained in 63 wells, 54 active producers and 5 active injectors and 4 long term shut in wells. This equates to gathering pressure data in 61 % of active producers and 10% of active injectors. Exhibit 2-G provides a 2009 monthly summary of individual well injection rate and injection pressure data for all of the Kuparuk River Oil Pool injectors. bp Exhibit 2-A . K~p(1ruk Waterflood Pattern Map Milne Point Field,2009 Kuparuk Well status :t;i:: .Abandon ed ,P' Gas Injector Injecting ;I .ff Miscible Injector Shut-In Not Yet Completed . "*" NulVUnknCM'll • Oii Prodlcer FIO'Mng ...-OU ProdUcer Shut· In 4'-Oii ProdUeer Submersible --on &Jsp ended OllWell 4-Plugged Back For Ream -} &Jspended ,i' Wiier Injector Injecting + Oii Prodlcer Gas Lift )/ \Miter Injector Shut-In -*-Oii F'fodlcer Hydraulic Pufl1l C::::J '-t1ne POint Unit I::] K/Jparuk Hydrau l c Units 0.5 2 3 4 - ----Miles 165 390 Exhibit 2-B BP ALASKA -Milne Point Unit Kuparuk Reservoir, Total Production 1000000 -,.--,--,..._,..__,__,.,_....,._...,.--,.---,---r--ir--.,..--ro--.--r---r---r__,.r--.,-..,.--.---..,..-..,.--,,..--y-1000000 ~ :;:::-> <( <( 0 em IJl I- I-CJ) CJ) - -IJl IJl I- I-CJ) CJ) :iE :iE --'O 'O 0 0 .. .. a.. a.. .. -Q) ·--o~ ...• 1. 100000 ~tttJ±lttt~fJ~R;f:a!1:a 100000~ Q) c: :::i c: 0 UI .. Q) u :I 'O 0 D:. "" -::!! 0 -:I 0 li; -as 3: I ~ 10000 l ii: 0 I I f 10000 ~ 1000 ., I I V · 1000 100 100 10 I +--+---+~+--+--+---+~+--+--+---+~+--+--+---l~+--+--+--l~+--+--+--l!--+--+--+10 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 -oil Prod Cum KUP -oil Prod Rate KUP -water Prod Cum KUP -Gas Prod Cum KUP -Gas Prod Rate KUP 100 ~..,...._,__,..__,__,.,_..,-....,...._,_--,-__,.__,.,_..,-....,.......,...._,..__,...,....,.......,._..,.......,....__,..__,...,....,.......,._~1.0 90 ' I I 14>-+ 0.9 80 70 0.7 60 j..j..-.jWI. I i,.;; I I 0 . 6 8 50 ~· I II'"! I 0.5 ~ 40 ' f I 1 · -I ;II'" I I ., I I ~ I I 0.4 30 '---t----,f--+---+----+---+--+---+--+---l--+ 0.3 20 la!• I IE111 1 I I I I lll I I I I I I I I I I I I I 0.2 10 +---cnr l I 11" I I I I I I I I I 0.1 o I.. 5 ? I I I I I I I I I I I I I I I I I I o.o 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 [-water Cut% KUP _-+-Producers Online -*"""Gas/Oil Ratio KUP \ 0 C> u: 0 CJ) :ii: ~ 'O 0 .. a.. UI IU C> 2009 production_injection.xls 3/24/2010 ):' <( 0 -ID I-en ai I-en ~ c 0 :;::: u GI c ... GI -Ill 3: 1000000 100000 10000 1000 100 10 Exhibit 2-C BP ALASKA -Milne Point Unit Kuparuk Reservoir, Injection 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 -water lnj Cum KUP -water lnj Rate KUP -Gas lnj Cum KUP --*-Gas lnj Rate KUP -solvent lnj Cum KUP _...,_Solvent lnj Rate KUP 50 45 40 35 GI c ~ 30 0 II) 0 25 -u GI :E' 20 0 * 15 10 5 0 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 I• Water Injectors Online • Gas Injectors Online •Ml Injectors Online I 2009 production_injection .xls 10000000 1000000 >~ <E! C IL ii: u u Ill 100000 Ill ::E ::E u: u:~ ~ ::E ::E ::E ::i;- -c c .2 10000 .2 1l 1l c c= - c .. ., ., > Cl 3i 1000 100 3/24/2010 Exhibit 2-D Milne Point Unit -Kuparuk River Oil Pool SUMMARY OF PERTINENT DATA WATERFLOOD START-UP DATE: PRODUCTION Prior to Waterflood Start-Up: Oil (MSTB) Gas (MMSCF) Water (MSTB) Since Waterflood Start-Up: Oil (MSTB) Gas (MMSCF) Water (MSTB) FLUID INJECTION Since Waterflood Startup: As of December 31, 2009 Injection Water (MSTB) Injection Gas (MMSCF) Lean Gas (MMSCF) Solvent (MMSCF) AVERAGE OF PRESSURES OBTAINED IN 2009@7,000' TVD ss December , 2009 Pressure (psig) WELL COUNT (Wells in Operation)* Production Wells WAG Injection Water Only Injection Gas Only Inject ion Notes: * Reflects ONLY operating wells . November 1985 0 0 0 220,853 119,224 232,937 404,631 98,732 90,310 8,422 2 ,808 88 24 23 Exhibit 2-E RESERVOIR VOIDAGE BALANCE January -December 2009 Production: Injection: Oil Water Gas Reservoir Water Gas Month Prod Rate Prod Rate Prod Rate Voidage lnj Rate lnj Rate (stb/day) (stb/day) (mscf/day) (rbbVday) (stb/day) (mscf/day) 1 /31 /2009 20492.03226 60008.03226 13955.58065 93,197 59939 9975 2/28/2009 20838.5 58998.53571 13384.57143 91,921 58650 8584 3/31/2009 20639.3871 59781 .64516 15562.45161 94,687 61605 9911 4/30/2009 20760.56667 57998.3 17754.66667 95,152 69550 11334 5/31/2009 21554.41935 55297.58065 19710.70968 95,059 64771 13388 6/30/2009 20967.53333 56563.46667 18667.43333 94,783 53fiT1 12411 7/31/2009 17124.41935 54400.80645 11792.93548 82,389 39292 6380 8/31/2009 18342.09677 62345.48387 13431 .87097 93,111 58440 7881 9/30/2009 18564..23333 57977.63333 14471 .43333 89,905 59304 9749 10/31/2009 18822.41935 56585.80645 14985 89,232 68680 10002 11/30/2009 18260..23333 50759 13963.36667 81,801 70233 8907 12131/2009 17057.93548 52094.54839 13594.35484 81,707 67290 8317 Average: 2009 19,452 56,906 15,106 90,245 60,944 9,737 Cumulative: mstb mstb mmscf mrb mstb mmscf 31-Dec-09 22D,853 232,937 119,,224 553,629 404,631 98,732 Page I Voidage Replacement (rbbVday) 70,690 68,007 72,317 81,787 78,965 66,637 46,183 67,100 69,822 79,587 80,083 76,513 71,474 mrb 508,207 Milne Point Unit Kuparuk River Oil Pool Voidage Voidage Replacement Balance Ratio (rbbVday) 0 .76 -22 ,507 0 .74 -23,914 0 .76 -22,370 0 .86 -13,365 0 .83 -16,094 0 .70 -28,146 0.56 -36,207 0 .72 -26,011 0.78 -20,083 0.89 -9,645 0.98 -1,718 0.94 -5,194 0.79 -18,771 mrb 0 .92 -45,421 Exhibit 2-F Static Pressure Data Kuparuk River Oil Pool ST ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: BPXA 2. Address: 900 E. Be nson Blvd Anchorage, Alaska 99508-4254 3. Un it or Lease Name : Milne Point 4. Fi eld and Pool : Kuparuk River Pool 5. Datu m Refere nce: 7000' SS Oil Gravity: API -23 7. Gas Gravity: Air = 1 .0 8. Wel l Na me 9. API Number 10. Oil (0) or 11 . AOGCC Pool 12. Fina l Test 13. Shu t-In 14. Press . 15. B.H. 16. Dep th Tool 17. Final 18. Da tum 19. Pressure 20. Comments Zone and Number: 50-XXX-XXXXX-XX-XX Gas (G) Code Da te T ime, Hours Surv. Type Temp. TVDss Pressure at TVDss Gradient, psi/ft. Pressure at (s ee Tool Dep th (input) Datum (cal) instructions for codes ) MPB-04A 50-500-29207-48-01 PROD 525100 2/23/2009 90 SBHP 170 6821.86 2008.00 7 ,000 0.058 2,018.40 B+C MPB-06 50-500-29212-76-00 PROD 525100 3/31/2009 26,791.20 SBHP 175 6811.92 3964.00 7,000 0.397 4,038.67 c MPB-09 50-500-29212-97-00 PROD 525100 3/19/2009 1, 108.97 SBHP 171 6848.78 2539.00 7,000 0.323 2,587.83 B+C MPB-20 50-500-29215-24-00 PROD 525100 3/16/2009 53 ,482.93 SBHP 171 6926.08 2431.00 7,000 0.308 2,453.79 B+C MPB-21 50-500-29215-35-00 PROD 525100 3/17/2009 972.27 SBHP 178 7009.00 2435.00 7,000 0.337 2,431.97 B MPB-21 50-500-29215-35-00 PROD 525100 3/18/2009 996.27 SBHP 178 7009.00 2435.00 7,000 0.337 2,431.97 B MPB-23 50-500-29219-15-00 PROD 525100 4/29/2009 68,706.32 SBHP 143 6230.33 3750 .00 7 ,000 0.358 4 ,025.79 A2+A3+B+C MPC-01 50-500-29206-63-00 PROD 525100 3/28/2009 137.43 SBHP 177 6683.02 1916.00 7 ,000 0.366 2 ,032.10 C+A3+A2 MPC-01 50-500-29206-63-00 PROD 525100 5/1/2009 980 pp 170 6728.91 2325.00 7 ,000 0.409 2,436 C+A3+A2 MPC-01 50-500-29206-63-00 PROD 525100 10/14/2009 1,896 pp 6726.92 2468.00 7,000 0.410 2 ,580 C+A3+A2 MPC-05A 50-500-29212-44-01 PROD 525100 6/20/2009 11,925.50 SBHP 7052.00 3908.00 7,000 0.423 3,886 B+C MPC-13 50-500-29213-28-00 PROD 525100 3/29/2009 1,147.53 SBHP 173 6655.04 2568.00 7 ,000 0.362 2 ,692.84 A2+A3+B+C MPC-13 50-500-29213-28-00 PROD 525100 4/27/2009 1,848 pp 6700.11 2788 .00 7,000 0.430 2 ,917 A2+A3+B+C MPC-14 50-500-29213-44-00 PROD 525100 1/2/2009 120 pp 6742.58 2211.00 7 ,000 0.427 2,321 A2+A3+B+C MPC-19 50-500-29215-04-00 INJ 525100 2/19/2009 1,352.58 SBHP 153 6931.38 3950.00 7,000 0.435 3,979.84 A 1 +A2+A3+B+C MPC-23 50-500-29226-43-00 PROD 525100 10/30/2009 72 pp 210 8580.00 3494.00 7,000 0 .041 3,559.00 SAG MPC-24 50-500-29230-20-00 PROD 525100 7/25/2009 264 pp 6072.25 1568.00 7,000 0.425 1,962 C+A3+A2 MPC-24 50-500-29230-20-00 PROD 525100 7/25/2009 PBU 7,000 0.318 2,226 C+A3+A2 MPC-24 50-500-29230-20-00 PROD 525100 11/16/2009 137 03 SBHP 166 6030 .18 1631.00 7,000 0.425 2,042.94 A2+A3+B+C MPC-24 50-500-29230-20-00 PROD 525100 11/18/2009 172 pp 6072.00 1700.00 7 ,000 0.440 2 ,108.00 C+A3+A2 MPC-26 50-500-29226-34-00 PROD 525100 8/8/2009 PBU 7,000 0.399 2,795 A2+A3+B+C MPC-26 50-500-29226-34-00 PROD 525100 8/8/2009 432 SBHP 164 6465.54 2110.00 7,000 0.410 2,329 A2+A3+B+C MPC-43 50-500-29232-00-00 PROD 525100 1/16/2009 2,328.17 SBHP 166 6984 .96 3007 .00 7,000 0.431 3,013.48 A1+A2+A3 MPC-43 50-500-29232-00-00 PROD 525100 2/19/2009 3,144 pp 6429.56 2798.00 7,000 0.435 3,046 A1+A2+A3 MPC-43 50-500-29232-00-00 PROD 525100 7/21/2009 168 pp 6429.56 1616.00 7,000 0.410 1,850 A1+A2+A3 MPE-04 50-500-29219-97-00 PROD 525100 7/26/2009 288 pp 6769 .03 1141.00 7,000 0.442 1,2 43 B+C MPE-08 50-500-29221-56-00 PROD 525100 5/21/2009 8,268.75 SBHP 168 6665 .63 2532.00 7,000 0.431 2 ,676.26 B+C MPE-08 50-500-29221-56-00 PROD 525100 12/19/2009 13,359.40 SBHP 166 6673.79 2542.00 7,000 0 .383 2 ,6 66.92 B+C MPE-14 50-500-29227-34-00 PROD 525100 7/25/2009 264 pp 6814 .96 2875.00 7,000 0.438 2 ,956 B+C MPE-14 50-500-29227-34-00 PROD 525100 10/30/2009 153.7 SBHP 178 6774.92 2819.00 7,000 0.436 2,917.09 B+C MPE-14A 50-500-29227-34-01 PROD 525100 12/29/2009 SBHP 166 6697.57 2924.00 7,000 0.441 3,057.40 B+C MPE-17 50-500-29226-87-00 INJ 525100 1/13/2009 696 PFO 7,000 0.579 4,053 B+C MPE-22 50-500-29225-67-00 PROD 525100 2/17/2009 96 pp 6816.39 2839.00 7,000 0.441 2,920 B+C MPF-06 50-500-29226-39-00 PROD 525100 3/4/2009 409.4 SBHP 175 6845 .32 3084.00 7,000 0.423 3, 149.48 A1+A2+A3 MPF-06 50-500-29226-39-00 PROD 525100 3/26/2009 936 pp 173 6883.28 3323.00 7,000 0.437 3,374 A1+A2+A3 MPF-18 50-500-29226-81-00 PROD 525100 7/29/2009 350 pp 184 7003 .00 3314.00 7,000 0.366 3312.90 A1+A2+A3 MPF-22 50-500-29226-32-00 PROD 525100 7/25/2009 251 pp 166 6638.00 2888.00 7 ,000 0.424 3041.49 A1 MPF-25 50-500-29225-46-00 PROD 525100 1/7/2009 480 pp 7033 .34 2495.00 7,000 0.420 2,481 A1+A2+A3 MPF-34 50-500-29228-24-00 PROD 525100 12/13/2009 1247 pp 186 7492.00 2362.00 7,000 0.362 2183.90 A1+A2+A3 MPF-37 50-500-29225-48-00 PROD 525100 1/5/2009 72 pp 178 7142 .00 1958.00 7,000 0.419 1898.50 A1+A2+A3 MPF-45 50-500 -292 25-56 -00 PROD 525100 7/21/2009 158 pp 177 6963.00 2083.00 7,000 0.406 2098.02 A1+A2+A3 MPF-50 50-500-29227-56-00 PROD 525100 10/30/2009 88 pp 174 7025 .00 1354.00 7 ,000 0.386 1344.35 A1+A2+A3 MPF-53 50-500-29225-78-00 PROD 525100 1/6/2009 72 pp 176 6882 .00 2692.00 7 ,000 0.421 2741.68 A1+A2+A3 MPF-57A 50-500-29227-4 7-01 PROD 525100 7/22/2009 171 SBHP 165 6487.82 3187.00 7 ,000 0.361 3,372 A Exh ibit 2-F Static Pressure Data Kuparuk River Oil Poo l 8. Wel l Nam e 9 . API Numb er 10. Oi l (O )or 11 . AOGCC Poo l 12 . Fin al Test 13 . Shut-In 14 . Press . 15 . B.H. 16. Depth Tool 17 . Final 18 . Da tum 19. Pre ss ure 20 . Comm en ts Zone an d Nu mber: 50 -XXX-XXXXX-XX-XX Gas (G ) Code Date Time . Hours Surv. Type Temp . TVDss Press ure at T VDss Gradient, psi/ft. Press ure at (s ee Tool Depth (i npu t) Datum (ca l) in st ruct ion s for codes) M PF-65 50 -500-29227 -52 -00 PROD 525100 9/11/2009 405.47 S BH P 193 6808.65 1870.00 7 ,000 0.370 1,940.71 A1+A2+A3 M PF-69 50 -500-29225-86-00 PROD 525 100 8/10/2009 645 pp 171 6997 .00 30 16 .00 7 ,000 0.366 30 17.10 A 1+A2+A3 M PF-78 50-500-29225-99-00 PROD 525100 7/25/2009 256 p p 192 7 17 1.00 370 1.00 7 ,000 0.408 3631.23 C+A 1+A2+A3 M PF-79 50 -500 -29228-13-00 PROD 525 100 5/4/2009 575.68 SB HP 163 62 4 0.60 340 7 .00 7,0 00 0.447 3,7 46.59 A1 MP F-79 50-500 -29228-13 -00 PROD 525100 5/30/2009 1207 pp 159 6268.00 3816.00 7,000 0.401 4 109.53 A1+A2+A3 MP F-80 50 -500 -29229-28-00 PROD 525100 5/19/2009 28 1.33 SB HP 182 677 1.05 388 0.00 7 ,000 0.43 1 3 ,978 .59 A2+A3 M PF -8 1 50-500-29229-59-00 PRO D 525 100 3/11/2009 182 .6 SB HP 169 6427 .87 2850 .00 7,000 0.4 14 3,087.09 A1+A2+A3 M PF-81 50 -500 -29229-59-00 PROD 525 100 4/6/2009 792 p p 157 649 1.20 335 1.00 7,000 0.432 3,57 1 A1+A2 +A3 MPF-86 50-500 -29230-18-00 PRO D 525100 4/5/2009 7 13.7 SB HP 177 6766.26 302 4 .00 7 ,000 0.37 7 3,11 2 .06 A2 MPF-86 50-500-29230-18-00 PROD 525100 51712009 1,494 .30 SB HP 174 6768.19 3258.00 7,000 0.365 3 ,342 .70 A2 M PF -86 50-500 -29230-18-00 PROD 525 100 5/16/2009 1708 pp 175 6853.00 333 1.00 7,000 0 .37 3385 .39 A1+A2+A3 MPF-86 50-500 -29230-18-00 PROD 525100 7/22/2009 185 pp 181 6853.00 2727.00 7,000 0 .37 278 1.39 A 1+A2 +A3 M PF -86 50-500 -29230-18-00 PRO D 525 100 11 /6/2009 3 11 p p 179 68 53.00 3026 .0 0 7,0 00 0.3 7 3080.39 A 1+A2 +A3 MP F-87A 50-500 -29231-84-01 PROD 525100 8/1/2009 4 19 .1 2 SBH P 179 6954.90 2946.00 7,000 0.434 2,965 .56 A1+A2+A3 MP F-87A 50-500 -29231-84-0 1 PRO D 525100 9/16/2009 1531 pp 176 70 11 .00 34 40 .00 7,000 0 .366 3435 .97 A1+A2+A3 MP F-92 50-500-292 29-24-00 INJ 52510 0 6/8/2009 265 .68 S BH P 140 6997.20 54 4 5.00 7,000 0.42 1 5,446 .18 A 1+A2+A3 MP F-94 50-500 -29230 -40 -00 PROD 525100 4/10/2009 263.23 S BHP 178 6986 .79 3123.00 7,0 00 0.9 49 3 , 135.53 A 1+A2+A3 MPF-94 50-500-29230 -40-00 PROD 525100 5/26/2009 177 .75 S BHP 185 723 1.15 3142.00 7 ,000 0.448 3,038 .52 A 1+A2+A4 M PF-94 50-500-29230-40-00 PROD 525100 5/29 /2009 228 .38 SB HP 182 7231 .15 33 17 .00 7 ,000 0.434 3,2 16 .68 A 1+A2+A5 M PF-94 50-500-29230-40-00 PROD 525100 6/9/2009 503 pp 178 7282 .00 3662.00 7,000 0.42 3543 .56 A 1+A2+A3 M PF -94 50 -500-29230 -40-00 PROD 525100 12/31/2009 864 p p 180 7282.00 3673.00 7 ,000 0.42 3554.56 A 1+A2 +A3 MPF-96 50 -500-29234 -06-00 PR OD 525 100 4/22/2009 pp 170 638 5 .00 2562.00 7 ,000 0.403 2809.85 A 1+A2+A3 MP F-96 50 -500 -29234-06-00 PROD 525100 9/12/2009 11 19 p p 170 6384.00 2395 .00 7 ,000 0.399 2640 .78 A1+A2+A3 MP F-96 50 -500 -29234-06-00 PROD 525 100 10 /2/2009 408 p p 6296.00 2453 .00 7 ,000 0.401 2,735 .00 A3+A2 +A1 M PF-96 50 -500-29234 -06-00 PROD 525 100 12/2 1/2009 756 p p 170 6384 .00 2267.00 7 ,000 0.4 25 13.40 A 1+A2+A3 M PH -05 50 -500-29225-72-00 PROD 525100 1/2/2009 96 pp 6604.39 2667.00 7,000 0.440 2,84 1 c M PH -05 50 -500-29225-72-00 PRO D 525100 7/26/2009 265 pp 163 6604 .39 2685.00 7 ,000 0.435 2,857 c MPJ-06 50 -500 -29224-93-00 PROD 525100 1/2 /2009 120 p p 167 6592.20 197 1.00 7 ,000 0.429 2 ,146 B+A3+A2 M PJ-06 50-500 -29224-93 -00 PROD 525 100 7/24/2009 208 pp 16 7 6592 .20 1955 .00 7 ,00 0 0.429 2,130 B+A3+A2 MPJ-10 50-500 -29225-00-00 PROD 525 100 7/28/2009 3 18 p p 6709 .35 278 7 .00 7,000 0.430 2,912 A2+A3+B M PK-02 50-500 -29226-75 -00 PROD 525 100 2/17/2009 168 pp 69 51 .00 1526.00 7,0 00 0.429 1,54 7 c MPK-06 50-500-29227 -25 -00 PROD 525100 2/17/2009 168 pp 675 4 .00 1800.00 7,000 0.443 1,909 c MP K-06 50-500-29227-25-00 PROD 525100 7/25/2009 264 p p 6754 .00 1806 .00 7 ,000 0.443 1,915 c MPK-09 50-500-29232 -4 7-00 PROD 525100 2/17/2009 168 pp 6984.00 2333.00 7,000 0.438 2 ,340 c MPK-13 50-500 -29226 -55 -00 PROD 525100 2/17/2009 168 pp 683 4 .00 1626.00 7 ,000 0 .440 1,699 c MPK-13 50-500-29226 -55 -00 PROD 525100 7/25/2009 264 p p 683 4 .00 1639.00 7,000 0.4 40 1,712 c MPK-30 50-500-29227-11 -00 PROD 525100 3/30 /2009 3 192 pp 6948 .00 2862 .00 7,000 0.442 2 ,885 B+C M PK-38 50-500-29227-1 1-00 PROD 525100 2/17/2009 168 pp 6959 .00 1478 .00 7,0 00 0.439 1,496 B+C MPL -02 50-500-292 19-9 8-00 PROD 525100 1 1/29/2009 64 .67 SB HP 185 6846.77 1810 .00 7 ,000 0.441 1,877.5 1 A1+A2+A3+B MPL-05 50-500-29220 -30-00 PROD 525 100 1/5/2009 833.78 SB HP 190 7022.78 2 128.00 7,000 0.365 2,11 9.68 C+B+A3+A2 +A 1 M PL -06 50 -500-29220-03-00 PRO D 525100 7/25/2009 264 pp 180 6872.37 2601.00 7,000 0.43 1 2 ,656 C+B+A3+A2+A 1 M PL -09 50 -500-29220-75-00 INJ 525100 1/3 1/2009 5 ,566 .80 SB HP 138 7000 .35 4069.00 7 ,000 0 .000 4 ,069 C+B+A3+A2+A 1 M PL -11 50-500-29223-36-00 PROD 525100 2/16/2009 233 .03 SB HP 192 69 18 .00 3404.00 7,000 0.432 3,439.46 C+B+A3+A2+A 1 M PL -1 1 50 -500-29223 -36 -00 PROD 525100 6/6/2009 10 5.53 S BH P 202 6926.43 3 199.00 7 ,000 0.438 3,23 1.24 C+B+A3+A2+A 1 M PL-1 2 50 -500 -29223 -34-00 PRO D 5251 00 1/6/2009 4 ,33 1.15 S BHP 17 8 6708.24 2432 .0 0 7 ,000 0 .072 2 ,4 52 .99 C+B+A3+A2+A 1 MP L-13 50 -500 -29223-35-00 PROD 525100 7/21 /2009 168 pp 176 6897.49 2241.00 7 ,000 0.4 19 2 ,284 C+B+A3+A2+A 1 M PL-15 50-500-29224-73-00 INJ 525 100 1/3/2009 384 PF O 7 ,000 0 .746 5,222 C+B+A3+A2+A 1 MPL-20 50-500-29227-90-00 PRO D 525 100 10/28/2009 153 pp 165 3065 .83 2685.00 7 ,000 0.092 3,048 A3+A2 M PL-29 50 -500 -29225-43-00 PRO D 525100 2/2 7/2 009 95 .02 SB HP 225 7056 .30 26 12 .00 7 ,000 0.36 1 2,59 1.66 C+B +A3+A2 +A 1 MP L-29 50-500 -29225-43-00 PRO D 525 100 6/3/2009 329 .73 S BH P 194 705 0 .09 2475.00 7 ,000 0.433 2 ,4 53.3 1 C+B+A3+A2+A 1 MP L-29 50-500-29225-43 -00 PROD 525 100 7/28/2009 312 p p 187 7085 .67 2447 .00 7 ,000 0.409 2,4 12 C+B+A3+A2+A 1 MPL-29 50-500 -29225-43-00 PRO D 525 100 10/5/2009 1,973 .05 SB HP 190 7047.70 2670.00 7 ,000 0.3 57 2,652 .96 C+B +A3+A2+A 1 M PL-36 50 -500 -29227-9 4-00 PROD 525100 5/30/2009 5,352 SB HP 6 155 .62 2605.00 7 ,000 0.4 13 2,954 A3+A2 Exhibit 2-F Static Pressure Data 8. Well Name 9. AP I Nu mber 10. Oi l (0) or 11. AOGCC Pool 12. Fina l Test 13. Shut-In 14. Press . 15 . B.H. 16. Depth Too l 17. Final 18. Datum and Number: 50-XXX-XXXXX-XX-XX Gas (G) Code Date Time, Hours Surv. Type Temp. TVDss Pressure at TVDss (see Tool Depth (input) instructions for codes) MPL-36 50-500-29227-94-00 PROD 525100 10/20/20 09 8,736 pp 6155.62 2647.00 7 ,000 MPL-43 50-500-29231-90-00 PROD 525100 5/20/2009 319.67 SBHP 179 6481.66 1852.00 7 ,000 21. All tests reported here in were made in accordance wit h the app licab le ru les, regu lations and instructions of the Alaska Oil and Gas Con lNJ ation Commission. Signature Printed Name FL PBU PFO pp SBHP Fluid Level Pre ssure Build Up Pressure Fall Off Pump Pressure ;hut-In Bottom Hole Pressure I he reby certify that the foregoing is true and correct to the best of my knowledge. Title Date Kuparuk River Oil Pool 19. Pressure 20. Comments Zone Gradient, psi/ft. Pressure at Datum (cal) 0.410 2,993 A3+A2 0.313 2,014.28 C+B+A3+A2+A1 Average 2,807 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPB-05A 1 /1 /2009 2 ,592 31 H20 13,848 446.70968 MPB-05A 2/1/2009 2,533.70 27 H20 10,829 401.07407 MPB-05A 3/1/2009 2,606.40 31 H20 17 ,238 556.06452 MPB-05A 4/1/2009 2,677 .60 30 H20 18 ,026 600.86667 MPB-05A 5/1/2009 2,689 31 H20 18 ,304 590.45161 MPB-05A 6/1/2009 2,663.40 30 H20 13 ,25 1 441.7 MPB-05A 7/1 /2009 2,586.10 30 H20 8,414 280.46667 MPB-05A 8/1/2009 2,639.30 31 H20 19 ,914 642.3871 MPB-05A 9/1/2009 2,553.30 30 H20 10 ,380 346 MPB-05A 10/1/2009 2,527 .80 31 H20 10 ,332 333.29032 MPB-05A 11/1/2009 2,562 .20 30 H20 9,344 311.46667 MPB-05A 12/1 /2009 2,601 .60 31 H20 16 ,288 525.41935 MPB-08 1/1/2009 0 H20 0 MPB-08 2/1/2009 0 H20 0 MPB-08 3/1/2009 0 H20 0 MPB-08 4/1/2009 0 H20 0 MPB-08 5/1/2009 0 H20 0 MPB-08 6/1/2009 0 H20 0 MPB-08 7/1/2009 0 H20 0 MPB-08 8/1/2009 0 H20 0 MPB-08 9/1/2009 0 H20 0 MPB-08 10/1/2009 0 H20 0 MPB-08 11 /1 /2009 0 H20 0 MPB-08 12 /1 /2009 0 H20 0 MPB-11 1/1/2009 0 H20 0 MPB-11 2/1/2009 0 H20 0 MPB-11 3/1/2009 0 H20 0 MPB-11 4/1/2009 0 H20 0 MPB -11 5/1/2009 0 H20 0 MPB-11 6/1/2009 0 H20 0 MPB-11 7/1/2009 0 H20 0 MPB-11 8/1/2009 0 H20 0 MPB-11 9/1/2009 0 H20 0 MPB-11 10 /1/2009 0 H20 0 MPB-11 11/1/2009 0 H20 0 MPB-11 12 /1/2009 0 H20 0 MPB-12 1/1/2009 2,430 .90 31 H20 61,005 1,967.90 MPB-12 2/1/2009 2,467 .30 28 H2 0 56,501 2 ,017 .89 MPB-12 3/1/2009 2,549.20 31 H20 69,329 2,236.42 MPB-12 4/1/2009 2,628.70 30 H20 71,351 2 ,378.37 MPB-12 5/1/2009 2,649.20 31 H20 71,129 2,294.48 MPB-12 6/1/2009 2 ,623.60 30 H20 66 ,301 2 ,210 .03 MPB-12 7/1/2009 2 ,559 .50 31 H20 63,466 2,047 .29 MPB-12 8/1/2009 2,624.10 31 H20 66,539 2, 146.42 MPB-12 9/1/2009 2,532.10 29 H20 60,918 2, 100.62 MPB-12 10 /1/2009 2,502.10 31 H20 65,487 2,112.48 MPB-12 11 /1 /2009 2,544.80 30 H20 62,091 2,069.70 MPB-12 12/1 /2009 2 ,580 .90 31 H20 72,545 2,340 .16 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPB-14 1/1/2 009 2,380 31 H20 69 ,2 94 2,235 .29 MPB-14 2/1/2009 2,494.60 28 H20 70 ,867 2,530 .96 MPB-14 3/1/2009 2,572.70 31 H20 84,093 2,712 .68 MPB-14 4/1/2009 2,639 .60 30 H20 88,964 2,965.47 MPB-14 5/1/2 009 2,650.40 31 H20 91 ,2 18 2,942 .52 MPB-14 6/1/2009 2,626.70 30 H20 85,641 2 ,854 .70 MPB-14 7/1/2 009 2,560.90 31 H20 84,598 2,728 .97 MPB-14 8/1/2009 2,623.10 31 H20 91,536 2,952.77 MPB-14 9/1/2009 2 ,534 .70 30 H20 79 ,694 2,65 6.47 MPB-14 10/1/2 009 2 ,5 02 31 H20 86,480 2,789.68 MPB-14 11 /1 /2 009 2,544.70 30 H20 84,150 2,805 MPB-14 12/1/2 009 2,581 .60 31 H20 90,824 2,929.81 MPB-17 1/1/2 009 0 H20 0 MPB-17 2/1/2009 0 H20 0 MPB-17 3/1/2009 0 H20 0 MPB-17 4/1/2009 0 H20 0 MPB-17 5/1/2009 0 H20 0 MPB-17 6/1/2009 0 H20 0 MPB-17 7/1/2009 0 H20 0 MPB-17 8/1/2009 0 H20 0 MPB-17 9/1/2 009 0 H20 0 MPB-17 10/1/2 009 0 H20 0 MPB-17 11 /1 /2009 0 H20 0 MPB -17 12/1 /2009 0 H20 0 MPB-18 1 /1/2 009 0 H20 0 MPB-18 2/1/2009 2,408 10 H20 18 ,701 1,8 70.10 MPB-18 3/1/2009 2,53 1.40 31 H20 59 ,074 1,905.61 MPB-18 4 /1/2009 2,6 08 .10 30 H20 53,497 1,783.23 MPB-18 5/1/2009 2,631 .70 31 H20 46,726 1,5 07.29 MPB-18 6/1/2009 2,6 08.40 30 H20 41 ,755 1,39 1.83 MPB-18 7/1/2009 2,561.20 31 H20 42 ,9 4 3 1,38 5.26 MPB-18 8/1/2009 2,627 .10 31 H20 47 ,474 1,531.42 MPB-18 9/1/2009 2,540 30 H20 40 ,674 1,3 55.80 MPB-1 8 10 /1/2 009 2,505.90 31 H20 44 ,3 52 1,430.71 MPB-18 11 /1 /2 009 2,545.20 30 H20 47 ,625 1,587 .50 MPB-18 12/1/2009 2,581.80 31 H20 51,098 1,648 .32 MPB-25 1 /1 /20 09 0 H20 0 MPB-25 2/1/2009 0 H20 0 MPB-25 3/1/2 009 0 H20 0 MPB-25 4/1/2009 0 H20 0 MPB-25 5/1/2009 0 H20 0 MPB-25 6/1/2009 0 H20 0 MPB-25 7/1/2 009 0 H20 0 MPB-25 8/1/2009 0 H20 0 MPB -25 9/1/2009 0 H20 0 MPB-25 10 /1/2009 0 H20 0 MPB-25 11 /1 /2 009 0 H20 0 MPB-25 12 /1 /20 09 0 H2 0 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPC-02 1 /1 /2009 1 ,83 0 .10 31 H20 42,388 1 ,36 7.35 MPC-02 2/1/2009 1,728.80 28 H20 38,949 1 ,3 91 .04 MPC-02 3/1/2009 1 ,646.30 31 H20 38,436 1 ,239 .87 MPC-02 4/1 /2 009 1 ,64 7 30 H20 34,342 1 ,144.73 MPC-02 5/1/2009 1,574.90 31 H20 28,328 913 .80645 MPC-02 6/1/2009 1,813 30 H20 37,205 1 ,240 .17 MPC-02 7/1/2009 1,722.10 31 H20 29,912 964 .90323 MPC-02 8/1/2009 1 ,596 .20 31 H20 31,340 1 ,010 .97 MPC-02 9/1/2009 1,587.30 30 H20 29,713 990.43333 MPC-02 10/1/2009 1,550.70 31 H20 29,278 944.45161 MPC-02 11 /1 /2009 1 ,545.30 30 H20 26,113 870.43333 MPC-02 12/1 /2009 1,481.30 31 H20 22,913 739.12903 MPC-06 1 /1 /2009 3,381.70 30 GAS 31,598 1 ,053.27 MPC-06 2/1/2009 3,715.70 3 GAS 3,919 1 ,3 06.33 MPC-06 3/1/2009 0 GAS 0 MPC-0 6 4/1/2009 0 GAS 0 MPC-06 5/1/2009 1,653.80 29 H20 18, 150 625 .86207 MPC-06 6/1/2009 1,897.40 30 H20 32,027 1,067 .57 MPC-06 7/1/2009 2,104.30 31 H20 37,440 1 ,207.74 MPC-06 8/1/2009 2,244.80 31 H20 44,955 1,450 .16 MPC-06 9/1/2009 2,329.90 30 H20 60,453 2 ,015 .1 0 MPC-06 10/1/2009 2,232.60 31 H20 47 ,053 1 ,5 17 .8 4 MPC-06 11 /1 /2009 2,312.60 30 H20 47,134 1 ,57 1.13 MPC-06 12/1 /2009 2,322 .50 31 H20 52,371 1 ,68 9.39 MPC-08 1 /1 /2009 2,551 .60 31 H20 6,802 219.41935 MPC-08 2/1/2009 2,389.60 21 H20 2,889 137.57143 MPC-08 2/1/2009 3,640.10 6 GAS 983 163.83333 MPC-08 3/1/2009 4,242.20 31 GAS 27,876 899.22581 MPC-08 4/1/2009 4,306.20 30 GAS 57,469 1 ,9 15.63 MPC-08 5/1/2009 4,242 31 GAS 43,999 1,419.32 MPC-08 6/1/2009 4,142.10 30 GAS 29,068 968 .93333 MPC-08 7/1/2009 3,962.30 11 GAS 7,551 686.45455 MPC-08 7/1/2009 1,976 .9 0 4 H20 1, 135 283.75 MPC-08 8/1/2009 2,436.90 18 H20 7,180 398.88889 MPC-08 9/1/2009 2,498.40 30 H20 7,239 241.3 MPC-08 10/1 /2009 2,404.20 31 H20 6,719 216.74194 MPC-08 11 /1 /2009 2,506 .50 30 H20 8,182 272.73333 MPC-08 12/1/2009 2,541.90 31 H20 9 ,595 309.51613 MPC-10 1 /1 /2 009 2,276 31 H20 50 ,938 1 ,6 43.16 MPC-10 2/1/2009 2,842.10 28 H20 81,782 2,920.79 MPC-10 3/1/2009 2,574.70 31 H20 41 ,929 1 ,3 52 .5 5 MPC-10 4/1/2 009 2,444.80 30 H20 33,436 1 ,114.53 MPC-10 5/1/2009 2,394.50 31 H20 43,077 1 ,389.58 MPC-10 6/1/2009 2,354.70 30 H20 42,358 1,411.93 MPC-10 7/1/2009 2,407 .50 31 H20 48 ,198 1,554.77 MPC-10 8/1/2009 2,660.40 31 H20 50 ,6 01 1,632.29 MPC-10 9/1 /2 009 2,675.50 30 H20 44,753 1,491 .77 MPC-10 10/1/2009 2 ,559 .20 31 H20 37,763 1 ,218.16 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPC-10 11 /1 /2009 2,433 .70 30 H20 24,525 817.5 MPC-10 12 /1 /2 009 2,351.10 31 H20 23,476 757.29032 MPC-11 1 /1 /2009 0 H20 0 MPC-11 2/1/2009 0 H20 0 MPC-11 3/1/2009 0 H20 0 MPC-11 4/1/2009 0 H20 0 MPC-11 5/1/2009 0 H20 0 MPC-11 6/1/2009 0 H20 0 MPC-11 7/1 /2009 0 H20 0 MPC-11 8/1/2009 0 H20 0 MPC-11 9/1/2009 0 H20 0 MPC-11 10 /1/2009 0 H20 0 MPC-11 11/1 /2009 0 H20 0 MPC-11 12/1/2009 0 H20 0 MPC-12A 1/1/2009 0 GAS 0 MPC-12A 2/1/2009 0 GAS 0 MPC-12A 3/1/2009 0 GAS 0 MPC-12A 4/1/2009 0 GAS 0 MPC-12A 5/1/2009 0 GAS 0 MPC-12A 6/1/2009 0 GAS 0 MPC-12A 7/1/2009 0 GAS 0 MPC-12A 8/1/2009 0 GAS 0 MPC-12A 9/1/2009 0 GAS 0 MPC -12A 10/1/2009 0 GAS 0 MPC -12 A 11 /1 /2009 0 GAS 0 MPC-12A 12/1 /2009 0 GAS 0 MPC-15 1 /1 /2009 2,342.40 3 1 H20 62,324 2,010.45 MPC-15 2/1/2009 2 ,379.20 28 H20 50,595 1,806.96 MPC-15 3/1/2009 2,294 .90 31 H20 48,467 1,563.45 MPC-15 4/1/2009 2,402.40 30 H20 53,469 1,782.30 MPC-15 5/1/2009 2,343 .50 31 H20 43 ,663 1,408.48 MPC-15 6/1/2009 2 ,306 .30 30 H20 46,864 1,562.13 MPC-15 7/1/2009 2,253 .10 31 H20 40 ,028 1,291.23 MPC-15 8/1/2009 2,169 .20 3 1 H20 3 1,446 1,014.39 MPC-15 9/1/2009 2,438 .20 30 H20 71 ,308 2,376.93 MPC-15 10/1/2009 2,535.70 31 H20 73,979 2,386.42 MPC-15 11 /1 /2009 2,613 .50 30 H20 66 ,990 2,233 MPC-15 12/1/2009 2,725 .50 31 H20 77 ,772 2 ,508.77 MPC-17 1 /1 /2009 0 GAS 0 MPC-17 2/1/2009 0 GAS 0 MPC-17 3/1/2009 0 GAS 0 MPC-17 4/1/2009 0 GAS 0 MPC-17 5/1/2009 0 GAS 0 MPC-17 6/1/2009 0 GAS 0 MPC-17 7/1/2009 0 GAS 0 MPC-17 8/1/2009 0 GAS 0 MPC-17 9/1/2009 0 GAS 0 MPC-17 10/1/2009 0 GAS 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPC-17 11 /1 /20 09 0 GAS 0 MPC-17 12/1 /2 009 0 GAS 0 MPC-19 1 /1 /2009 0 H20 0 MPC-19 2/1/2009 2, 170.60 5 H20 12,209 2,441.80 MPC-19 3/1/2009 2,343 .10 31 H20 76,078 2,454.13 MPC-19 4/1/2009 2,519 .90 30 H20 83,296 2,776 .53 MPC-19 5/1/2009 2,565 .20 31 H20 85,499 2,758 .03 MPC-19 6/1/2009 2,570.10 30 H20 82,872 2 ,762.40 MPC-19 7/1/2009 2 ,505 .80 31 H20 74,997 2,419.26 MPC-19 8/1/2009 2 ,667 .30 31 H20 125,441 4,046.48 MPC-19 9/1/2009 2 ,597 .10 30 H20 107 ,8 61 3,595.37 MPC-19 10/1/2009 2 ,252 .10 31 H20 68,900 2,222.58 MPC-19 11 /1 /2009 2 ,247.20 30 H20 62,329 2,077.63 MPC-19 12/1 /2009 2, 156 .3 0 31 H20 54,410 1,755.16 MPC-25A 1 /1 /2009 0 GAS 0 MPC-25A 2/1/2009 0 GAS 0 MPC-25A 3/1/2009 0 GAS 0 MPC-25A 4/1/2009 0 GAS 0 MPC-25A 5/1/2009 0 GAS 0 MPC-25A 6/1/2009 0 GAS 0 MPC-25A 7/1/2009 0 GAS 0 MPC-25A 8/1/2009 0 GAS 0 MPC-25A 9/1/2009 0 GAS 0 MPC-25A 10/1 /2009 0 GAS 0 MPC-25A 11 /1 /2009 0 GAS 0 MPC-25A 12/1 /2009 0 GAS 0 MPC-28A 1 /1 /2009 1,394.40 31 H20 39,795 1,283.71 MPC-28A 2/1 /2009 1,483 .3 0 28 H20 34,416 1,229.14 MPC-28A 3/1/2009 1,661 .90 31 H20 67,434 2, 175 .29 MPC-28A 4/1/2009 1 ,799 .10 30 H20 63 ,057 2, 101 .90 MPC-28A 5/1/2009 1 ,588.40 31 H20 29,069 937 .70968 MPC-28A 6/1 /2009 1 ,63 9.80 10 H20 9,592 959.2 MPC-28A 6/1/2009 3,501 .60 21 GAS 38,406 1,828 .86 MPC-28A 7/1/2009 3,423 .80 31 GAS 31 ,072 1,002 .32 MPC-28A 8/1/2009 3,205 31 GAS 46,213 1,490.74 MPC-28A 9/1/2009 3,118 .70 30 GAS 60 ,0 15 2,000.50 MPC-28A 10/1 /2 009 2,976 .70 31 GAS 63,892 2,061.03 MPC-28A 11 /1 /2009 2,991 .8 0 30 GAS 60,100 2,003.33 MPC-28A 12/1 /2009 2,858.60 31 GAS 56,657 1 ,827.65 MPC-36 1 /1 /2 009 2,520 .20 24 H20 35,571 1,482.13 MPC-36 2/1/2009 2,339 .60 15 H20 18 ,677 1 ,245.1 3 MPC-36 3/1/2009 2,531.80 31 H20 36,043 1,162.68 MPC-36 4/1/2009 2,645 .20 30 H20 37, 158 1 ,238.6 0 MPC-36 5/1/2 009 2,402.10 31 H20 19,990 644.83871 MPC-36 6/1/2009 2,461.60 30 H20 21, 173 705.76667 MPC-36 7/1/2009 2,429.70 20 H20 12,836 641.8 MPC-36 8/1/2009 2,493 10 H20 6,099 609.9 MPC-36 8/1/2009 4 ,3 56.30 12 GAS 14,001 1 ,166.75 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPC-36 9/1/2009 4,384.40 30 GAS 40,478 1,349 .27 MPC-36 10 /1/2009 4 ,271.50 31 GAS 47,958 1,547.03 MPC-36 11 /1 /20 09 2 ,507.50 8 H20 6,636 829.5 MPC-36 11 /1/2009 4,317.90 22 GAS 27 ,355 1,243.41 MPC-36 12/1 /2009 2,458 .20 31 H20 22,462 724.58065 MPC-39 1/1/2009 3,316.30 31 H20 36 , 126 1, 165.35 MPC-39 2/1/2009 3,301.40 28 H20 30 ,814 1,100.50 MPC-39 3/1/2009 3,244 26 H20 27 ,513 1 ,058.19 MPC-39 4/1/2009 3 ,265.50 30 H20 33 ,032 1 ,101 .07 MPC-39 5/1 /2009 2 ,715.50 31 H20 28 ,233 910 .74194 MPC-39 6/1 /2009 3,210.80 30 H20 29 ,606 986 .86667 MPC-39 7/1/2009 3, 179.40 20 H20 20 ,572 1,028.60 MPC-39 8/1/2009 3 ,012.50 21 H20 20 ,093 956.80952 MPC-39 9/1/2009 2,998.20 30 H20 19,454 648.46667 MPC-39 10/1 /2009 2 ,859.10 31 H20 20,571 663.58065 MPC-39 11 /1 /2009 3 ,097.80 22 H20 17 ,922 814 .63636 MPC-39 11 /1 /2009 4 ,826.40 9 GAS 2,701 300 .11111 MPC-39 12/1 /2009 4,547 .30 3 1 GAS 8 ,797 283 .77419 MPC-42 1/1/2009 4,571 .20 30 GAS 11 ,722 390.73333 MPC-42 1 /1 /2009 2 ,699 1 H20 1,283 1,283 MPC-42 2/1 /2009 4 ,481.20 28 GAS 15 ,099 539.25 MPC-42 3/1/2009 4,519.20 31 GAS 34 ,693 1,119.13 MPC-42 4/1/2009 4,534 30 GAS 41 ,382 1,379.40 MPC-42 5/1/2009 4,537.40 31 GAS 41,014 1,323.03 MPC-42 6/1/2009 4,446 30 GAS 33,092 1,103.07 MPC-42 7/1/2009 4,330.80 19 GAS 14 ,069 740.47368 MPC-42 7/1/2009 3,753.60 7 H20 27 3 .85714 MPC-42 8/1/2009 2,675 .90 10 GAS 769 76 .9 MPC-42 8/1/2009 1,793 .50 12 H20 11,375 947 .91667 MPC-42 9/1 /2 009 2 ,085 30 H20 32,283 1 ,076.10 MPC-42 10 /1/2009 1,877 .30 20 H20 33 ,380 1 ,669 MPC-42 10 /1/2 009 2 , 148.40 1 GAS 27 27 MPC-42 11 /1 /2009 2,344.40 30 H20 58,883 1,962 .77 MPC-42 12/1/2009 2,528 .30 31 H20 60 ,640 1 ,956.13 MPCFP-2 1/1/2009 0 H20 0 MPCFP-2 2 /1/2009 0 H20 0 MPCFP-2 3/1/2009 0 H20 0 MPCFP-2 4/1/2009 0 H20 0 MPCFP-2 5/1/2009 0 H20 0 MPCFP-2 6/1/2009 0 H20 0 MPCFP-2 7/1/2009 0 H20 0 MPCFP-2 8/1/2009 0 H20 0 MPCFP-2 9/1/2009 0 H20 0 MPCFP-2 10 /1/2009 0 H20 0 MPCFP-2 11 /1/2009 0 H20 0 MPCFP-2 12 /1/2009 0 H20 0 MPE-02 1 /1 /2009 0 GAS 0 MPE-02 2/1/2009 0 GAS 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPE-02 3/1/2009 0 GAS 0 MPE -02 4 /1/2 009 0 GAS 0 MPE-02 5/1/2009 0 GAS 0 MPE-02 6/1/2009 0 GAS 0 MPE -02 7/1/2009 0 GAS 0 MPE-02 8/1/2009 0 GAS 0 MPE -02 9/1 /2 009 0 GAS 0 MPE-02 10/1/2009 0 GAS 0 MPE-02 11 /1 /2009 0 GAS 0 MPE-02 12 /1 /2009 0 GAS 0 MPE-03 1 /1 /2 009 3,276 .60 31 GAS 32 ,673 1 ,053.97 MPE-03 2/1/2009 3, 175 .20 28 GAS 12,848 45 8 .85 71 4 MPE-03 3/1/2 009 3, 177.40 26 GAS 8,897 342.19231 MPE-03 4 /1/2 009 3,598.90 22 GAS 31,175 1,417.05 MPE-03 5/1/2 009 3,398.90 31 GAS 102,432 3,304.26 MPE-03 6/1/2009 3,4 29.30 30 GAS 86,433 2,881 .10 MPE-03 7/1/2009 3,362.50 28 GAS 36,826 1 ,31 5.2 1 MPE-03 8/1/2009 3,3 14.70 31 GAS 31,686 1 ,02 2 .13 MPE-03 9/1/2009 3,302.40 30 GAS 19,096 636.53333 MPE -03 10/1/2009 3 ,324 31 GAS 33,388 1 ,077.03 MPE-03 11 /1 /2009 3,372.80 30 GAS 36,974 1 ,232.47 MPE-03 12 /1 /2 009 3,408.70 31 GAS 41,682 1 ,344 .58 MPE-05 1 /1 /20 09 2,499.80 23 H20 43,095 1 ,873 .70 MPE-05 2/1/2009 0 H20 0 MPE-05 3/1/2009 0 H20 0 MPE-05 4/1/2 009 0 H20 0 MPE-05 5/1/2 009 0 H20 0 MPE-05 6/1/2009 0 H20 0 MPE-05 7/1/2 009 0 H20 0 MPE-05 8/1/2 009 0 H20 0 MPE-05 9/1 /2 009 0 H20 0 MPE-05 10/1/2 009 0 H20 0 MPE-05 11 /1 /2 009 0 H20 0 MPE-05 12/1 /2 009 0 H20 0 M PE-07 1 /1 /2 009 2,561.50 31 H20 76,639 2,472 .23 MPE-07 2/1/2 009 2,513.40 28 H20 69,850 2,494.64 MPE-07 3/1/20 09 2 ,523.90 24 H2 0 68,497 2 ,854 .04 MPE-07 4/1/20 09 2,485.70 23 H20 8 1,522 3,544.43 MPE-07 5/1/2009 2 ,618.90 22 H20 72,466 3,293 .91 MPE-07 6/1/2009 2,177 .70 14 H20 38 ,836 2,774 MPE-07 7/1/2009 2,265 .10 19 H20 51, 192 2,694 .32 MPE -07 8/1/2009 2,420 .80 26 H20 97,982 3,768.54 MPE-07 9/1/2009 2,579 30 H20 10 3 ,564 3,452 .13 MPE-07 10 /1/2 009 2,470.40 31 H20 97,675 3,150.81 MPE-07 11 /1/2009 2 ,604.60 30 H20 97,420 3,247.33 MPE-07 12 /1 /2009 2 ,629 .70 31 H20 100 ,641 3,2 46.48 MPE-16 1 /1 /2 009 2 ,631.60 25 H20 8 ,066 322.64 MPE-16 2/1/2009 0 H20 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPE-16 3/1/2009 0 H20 0 MPE-16 4/1/2009 1,914.10 10 H20 7,540 754 MPE-16 5/1/2009 0 H20 0 MPE-16 6/1/2009 0 H20 0 MPE-16 7/1/2009 0 H20 0 MPE-16 8/1/2009 0 H20 0 MPE-16 9/1/2009 0 H20 0 MPE-16 10/1 /2009 0 H20 0 MPE-16 11/1 /2 009 0 H20 0 MPE-16 12/1/2009 0 H20 0 MPE-17 1/1 /2009 2,321.10 18 H20 54,135 3,007 .50 MPE-17 2/1/2009 2,518 .80 28 H20 62,026 2,215 .21 MPE-17 3/1/2009 2,600.40 31 H20 80,876 2,608.90 MPE-17 4/1/2009 2,651.10 30 H20 65,672 2,189.07 MPE-17 5/1/2009 2 ,696.50 31 H20 70,238 2,265.74 MPE-17 6/1/2009 2,744.80 30 H20 64,899 2, 163.30 MPE-17 7/1/2009 2 ,521 .60 31 H20 51,882 1 ,673.6 1 MPE-17 8/1/2009 2,565 .60 31 H20 63,456 2 ,046 .97 MPE-17 9/1/2009 2 ,624.20 30 H20 59 ,925 1,997 .50 MPE-17 10/1/2009 2,480 31 H20 58,659 1,892 .23 MPE-17 11 /1/2009 2,652 .50 30 H20 66 ,763 2,225.43 MPE-17 12/1/2009 2,678.70 31 H20 70 ,809 2,284.16 MPE-23 1/1/2009 2,544.40 31 H20 101,635 3,278.55 MPE-23 2/1/2009 3,6 75.90 6 GAS 3,269 544.83333 MPE -23 2/1/2009 2 ,541.90 22 H20 67 ,120 3 ,050.91 MPE-23 3/1/2009 3,347 26 GAS 25,961 998.5 MPE-23 3/1/2009 3,622.40 3 H20 8,298 2 ,766 MPE-23 4/1/2009 6 ,934.40 3 GAS 5,043 1 ,681 MPE -23 4/1/2009 2 ,641.20 30 H2 0 106 ,159 3,538.63 MPE-23 5/1/2009 69 ,283 1 GAS 249 249 MPE-23 5/1/2009 2 ,668.90 3 1 H20 116 ,366 3 ,753.74 MPE-23 6/1/2009 2 ,707 30 H20 110,427 3,680.90 MPE-23 7/1 /2009 2,493.60 3 1 H20 105 , 189 3,393.19 MPE-23 8/1/2009 2,583.10 31 H20 115,622 3,729.74 MPE-23 9/1/2009 2,601 30 H20 110 , 154 3 ,671.80 MPE-23 10/1/2009 2,453.40 31 H20 106,398 3,432.19 MPE-23 11 /1 /2009 2 ,619.40 30 H20 110,433 3,68 1 .10 MPE-23 12/1/2009 2,641.20 31 H20 121 ,223 3 ,910 .42 MPE-26 1 /1 /2009 2,045.30 31 H20 58,382 1,883.29 MPE-26 2/1/2009 2 ,320 .90 28 H20 42,459 1,516.39 MPE-26 3/1/2009 2,449.30 31 H20 51,593 1,664.29 MPE-26 4/1/2009 2,507.90 30 H20 45,157 1,505.23 MPE-26 5/1/2009 2,600.90 31 H20 52 ,821 1 ,703 .90 MPE-26 6/1/2009 2,699 30 H20 50,807 1,693 .5 7 MPE-26 7/1/2009 2,531 31 H20 41 ,983 1,354.29 MPE-26 8/1/2009 4,280.80 7 GAS 5,591 798.71429 MPE-26 8/1/2009 2 ,523 .80 24 H20 35, 119 1,463.29 MPE-26 9/1/2009 4 ,045 30 GAS 67 ,364 2 ,245.47 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPE-26 10/1/2009 4 ,006.60 31 GAS 75 ,842 2,446.52 MPE-26 11 /1/2009 3,595.50 30 GAS 45 ,326 1,510.87 MPE-26 12 /1/2009 3,333.20 17 GAS 27 ,305 1 ,606 .18 MPE-26 12 /1/2009 2 ,212 .20 14 H20 25 ,647 1 ,831 .93 MPF-10 1/1/2009 4,447.20 31 GAS 46 ,612 1 ,503.61 MPF-10 2/1 /2009 4 ,370 .70 28 GAS 35 ,269 1 ,259.61 MPF-10 3/1/2009 4 ,332 .30 31 GAS 61 , 166 1 ,973.10 MPF-10 4/1/2009 3 ,324 3 GAS 3 ,535 1 ,178.33 MPF-10 4/1 /2009 1,851.50 7 H20 9 ,950 1,421.43 MPF-10 5/1/2009 0 H20 0 MPF-10 5/1 /2009 0 GAS 0 MPF-10 6/1 /2009 0 H20 0 MPF-10 6/1 /2009 0 GAS 0 MPF-10 7/1/2009 0 H20 0 MPF-10 7/1 /2009 0 GAS 0 MPF-10 8/1/2009 0 H20 0 MPF-10 8/1/2009 0 GAS 0 MPF-10 9/1/2009 0 H20 0 MPF-10 9/1/2009 0 GAS 0 MPF-10 10/1/2009 0 GAS 0 MPF-10 10/1/2009 0 H20 0 MPF-10 11 /1 /2009 0 H20 0 MPF-10 11/1 /2009 0 GAS 0 MPF-10 12/1 /2009 0 H20 0 MPF-10 12 /1/2009 0 GAS 0 MPF-17 1/1 /2009 0 H20 0 MPF-17 2/1/2009 0 H20 0 MPF-17 3/1 /2009 0 H20 0 MPF-17 4/1/2009 0 H20 0 MPF-17 5/1 /2009 0 H20 0 MPF-17 6/1/2009 0 H20 0 MPF-17 7/1/2009 0 H20 0 MPF-17 8/1/2009 0 H20 0 MPF-17 9/1/2009 0 H20 0 MPF-17 10/1/2009 0 H20 0 MPF-17 11 /1 /2009 0 H20 0 MPF-17 12 /1 /2009 0 H20 0 MPF-26 1/1 /2009 4,425 3 1 GAS 70 ,527 2 ,275 .06 MPF-26 2/1 /2009 4,3 19.50 19 GAS 42 ,530 2 ,238.42 MPF-26 2/1/2009 2 ,623.10 10 H20 16 ,618 1 ,661.80 MPF-26 3/1/2009 2,454 .20 3 1 H20 53,746 1 ,733.74 MPF-26 4/1/2009 2,486 .60 30 H20 50 , 169 1 ,672 .30 MPF-26 5/1/2009 2,564.60 31 H20 54,420 1,755.48 MPF-26 6/1 /2009 2,609.60 27 H20 49,086 1,818 MPF-26 7/1/2009 2 ,344.10 16 H20 25,453 1 ,590 .81 MPF-26 8/1/2009 2 ,218 .80 31 H20 43 ,734 1,410.77 MPF-26 9/1/2 009 2 ,031 30 H20 3 1,905 1 ,063 .50 MPF-26 10/1/2009 1 ,964 .50 3 1 H20 36,452 1 ,175.87 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPF-26 11 /1 /2009 2,001.50 30 H20 38 ,847 1,294.90 MPF-26 12/1/2009 1,980.40 17 H20 21, 132 1,243.06 MPF-26 12/1/2009 3 ,864.90 15 GAS 15 ,940 1,062.67 MPF-30 1/1/2009 2 ,357.80 31 H20 57,472 1,853.94 MPF-30 2/1/2009 4 ,393.90 7 GAS 1,584 226 .28571 MPF-30 2/1/2009 3,043.40 22 H20 51,724 2,351 .09 MPF-30 3/1/2009 4 ,380.60 31 GAS 53 ,383 1,722.03 MPF-30 4/1/2009 4 ,207.70 30 GAS 72 ,073 2,402.43 MPF-30 5/1/2009 3 ,692.30 6 GAS 5,266 877.66667 MPF-30 5/1/2009 2 ,309.40 25 H20 57,689 2,307 .56 MPF-30 6/1/2009 2,478.70 27 H20 52,238 1,934.74 MPF-30 7/1/2009 2,090 20 H20 26,527 1,326 .35 MPF-30 8/1/2009 2,283.70 31 H20 48,041 1,549.7 1 MPF-30 9/1/2009 2,243.60 30 H20 40,976 1,365.87 MPF-30 10/1/2009 2,510.20 31 H20 58 , 139 1,875.45 MPF-30 11/1/2009 2,740.50 30 H20 58,505 1,950.17 MPF-30 12/1/2009 2 ,916 .50 31 H20 64 ,174 2,070 .13 MPF-41 1 /1 /2009 0 H20 0 MPF-41 2/1/2009 0 H20 0 MPF-41 3/1/2009 0 H20 0 MPF-41 4/1/2009 0 H20 0 MPF-41 5/1/2009 0 H20 0 MPF-41 6/1/2009 0 H20 0 MPF-41 7/1/2009 0 H20 0 MPF-41 8/1/2009 0 H20 0 MPF-41 9/1/2009 0 H20 0 MPF-41 10/1/2009 0 H20 0 MPF-41 11 /1 /2009 0 H20 0 MPF-41 12/1/2009 0 H20 0 MPF-42 1 /1 /2009 4 ,210.40 23 GAS 51 ,569 2,242 .13 MPF-42 2/1/2009 4 ,398 .30 7 GAS 14 ,031 2,004.43 MPF-42 2/1/2009 2 ,531.10 22 H20 61 ,325 2,787 .50 MPF-42 3/1/2009 2 ,871.40 31 H20 90 ,222 2,910.39 MPF-42 4/1/2009 3,046.90 30 H20 87,021 2,900 .70 MPF-42 5/1/2009 3,179.80 31 H20 90,484 2,918 .84 MPF-42 6/1 /2009 3 ,273 .30 18 H20 55,409 3,078 .28 MPF-42 7/1/2009 0 H20 0 MPF-42 8/1/2009 1,941 .30 19 H20 24 ,203 1,273 .84 MPF-42 9/1/2009 4 ,074 .80 12 GAS 25,864 2 , 155 .3 3 MPF-42 9/1/2009 2 ,038 18 H20 22 ,648 1,258.22 MPF-42 10 /1/2009 4 ,083 .80 31 GAS 58 ,002 1,871.03 MPF-42 11 /1 /2009 3,889 .10 30 GAS 40,598 1,353.27 MPF-42 12 /1 /2009 1,805.90 31 H20 28,503 919.45161 MPF-46 1/1/2009 4,457.10 9 GAS 9,496 1,055.11 MPF-46 2/1/2009 0 GAS 0 MPF-46 3/1/2009 0 GAS 0 MPF-46 4/1/2009 2 ,212 .30 15 H20 36,889 2,459 .27 MPF-46 5/1/2009 4 ,502.30 5 GAS 3,328 665 .6 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL , MCF) (BBL, MCF) MPF-46 5/1/2009 2,753.50 27 H20 66,365 2,457.96 MPF-46 6/1/2009 2,869.80 29 GAS 67,898 2,341.31 MPF-46 7/1/2009 4,003.80 21 GAS 46,086 2 ,194.57 MPF-46 8/1/2009 3,764.10 30 GAS 66,890 2 ,229.67 MPF-46 9/1/2009 3,732.90 19 GAS 45,507 2,395.11 MPF-46 9/1/2009 1,779.40 11 H20 20 ,664 1,878.55 MPF-46 10/1/2009 2,260 3 1 H20 75,254 2,427 .55 MPF-46 11/1/2009 2 ,585 .90 30 H20 74,680 2,489.33 MPF-46 12 /1/2009 2,828 .90 31 H20 82,555 2,663.06 MPF-49 1 /1 /2009 1,708.30 31 H20 70,402 2,271.03 MPF-49 2/1/2009 1,910.50 28 H20 72,673 2 ,595.46 MPF-49 3/1/2009 1,921 .70 31 H20 68,798 2,219.29 MPF-49 4/1/2009 1,936.80 30 H20 62,901 2,096 .70 MPF-49 5/1/2009 2,005 .20 31 H20 65,975 2,128.23 MPF-49 6/1/2009 1,946.10 25 H20 51,240 2,049.60 MPF-49 7/1/2009 1,834.60 20 H20 37 ,019 1,850.95 MPF-49 8/1/2009 1 ,879.40 31 H20 52,835 1,704.35 MPF-49 9/1/2009 1,871.60 30 H20 46,714 1 ,55 7.13 MPF-49 10/1/2009 1,770.70 31 H20 40,920 1 ,320 MPF-49 11/1/2009 1,844.70 28 H20 43 ,620 1,557.86 MPF-49 11/1/2009 4,000.10 2 GAS 4,339 2,169.50 MPF-49 12/1 /2009 4,072.40 31 GAS 56 ,270 1 ,815.16 MPF-62 1/1/2009 1 ,729.20 31 H20 123,939 3,998 .03 MPF-62 2/1/2009 1 ,763.40 28 H20 102,823 3 ,672.25 MPF-62 3/1/2009 1 ,780.40 31 H20 109,274 3,524.97 MPF-62 4/1/2009 1 ,669.10 30 H20 97,868 3,262.27 MPF-62 5/1/2009 3,552.70 24 GAS 68,327 2,846.96 MPF-62 5/1/2009 1,645 7 H20 21,994 3,142 MPF-62 6/1/2009 3,4 19 .50 10 GAS 27 ,576 2,757.60 MPF-62 7/1/2009 0 GAS 0 MPF-62 8/1/2009 0 GAS 0 MPF-62 9/1/2009 128 2 H20 2,147 1,073.50 MPF-62 10/1/2009 389.4 3 1 H20 93 ,823 3,026.55 MPF-62 11 /1 /2009 690 .6 30 H20 99,407 3,313.57 MPF-62 12/1 /2009 893 .3 31 H20 101 ,871 3,286.16 MPF-70 1 /1 /2009 2,771 9 H20 22,981 2,553.44 MPF-70 1 /1 /2009 4 ,361 23 GAS 37 ,135 1 ,6 14.57 MPF-70 2/1/2009 4 ,185 .10 28 GAS 68,063 2,430.82 MPF-70 3/1/2009 2,208 2 H20 2,478 1,239 MPF-70 3/1/2009 4,107.50 29 GAS 79 ,847 2 ,753 .34 MPF-70 4/1/2009 1,771.20 30 H20 39,914 1 ,33 0.47 MPF-70 5/1/2009 1,688.30 3 1 H20 38,288 1 ,235.10 MPF-70 6/1/2009 1 ,562.30 25 H20 29,140 1,165 .60 MPF-70 7/1/2009 1,394 20 H20 19,939 996.95 MPF-70 8/1/2009 1,477 31 H20 36 ,020 1, 161.94 MPF-70 9/1/2009 1,513.10 30 H20 35,765 1 ,192.17 MPF-70 10/1/2009 1,457.90 31 H20 34,520 1 , 113 .55 MPF-70 11/1 /2009 1 ,569.80 30 H20 43,565 1,452 .17 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPF-70 12 /1/2009 1,626.50 31 H20 45,429 1,465.45 MPF-74 1 /1 /2009 0 H20 0 MPF-74 2/1/2009 0 H20 0 MPF-74 3/1/2009 0 H20 0 MPF-74 4/1/2009 0 H20 0 MPF-74 5/1/2009 0 H20 0 MPF-74 6/1/2009 0 H20 0 MPF-74 7/1/2009 0 H20 0 MPF-74 8/1/2009 0 H20 0 MPF-74 9/1/2009 0 H20 0 MPF-74 10/1/2009 0 H20 0 MPF-74 11 /1/2 009 0 H20 0 MPF-74 12/1 /2 009 0 H20 0 MPF-82 1/1/2009 0 GAS 0 MPF-82 2/1/2009 0 GAS 0 MPF-82 3/1/2009 0 GAS 0 MPF-82 4/1/2009 0 GAS 0 MPF-82 5/1/2009 0 GAS 0 MPF-82 6/1/2009 0 GAS 0 MPF-82 7/1/2009 0 GAS 0 MPF-82 8/1/2009 0 GAS 0 MPF-82 9/1/2009 0 GAS 0 MPF-82 10/1 /2 009 0 GAS 0 MPF-82 11/1 /2009 0 GAS 0 MPF-82 12 /1/2009 0 GAS 0 MPF-83 1/1/2009 2,790.60 24 H20 58 ,528 2,438.67 MPF-83 2/1/2009 3,022 .30 7 H20 18 ,653 2 ,664.71 MPF-83 2/1/2009 4,341 .20 21 GAS 42 ,746 2 ,035.52 MPF-83 3/1/2009 3,735 .80 5 GAS 11 ,943 2 ,388 .60 MPF-83 4/1/2009 1,632 .10 1 GAS 368 368 MPF-83 4/1/2009 2 ,775.80 25 H20 56 ,379 2 ,255 .16 MPF-83 5/1/2009 3,887.30 7 GAS 18,744 2,677 .71 MPF-83 6/1/2009 0 GAS 0 MPF-83 7/1 /2009 0 GAS 0 MPF-83 8/1/2009 0 GAS 0 MPF-83 9/1 /2009 0 GAS 0 MPF-83 10/1 /2009 1,796.60 29 H20 29 ,702 1,024.21 MPF-83 11 /1 /2009 4 ,011.80 7 GAS 12 ,739 1,819.86 MPF-83 11/1 /2009 1 ,816.40 24 H20 26,181 1,090.88 MPF-83 12/1 /2009 3 ,774.60 3 1 GAS 49 ,939 1,610 .94 MPF-848 1 /1 /2009 1 ,710 .80 28 H20 73 ,544 2,626.57 MPF-848 2/1 /2009 0 H20 0 MPF-848 3/1/2009 707.2 27 H20 29 ,014 1,074 .59 MPF-848 4/1/2009 852 .1 30 H20 54,842 1,828.07 MPF-848 5/1/2009 1,468.40 31 H20 97,122 3, 132 .9 7 MPF-848 6/1/2009 1,701 .90 27 H20 88,354 3 ,272 .37 MPF-848 7/1/2009 1,493.70 20 H20 52 ,724 2 ,636.20 MPF-848 8/1 /2009 1 ,659.30 31 H20 93 ,684 3,022.06 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPF-848 9/1 /2 009 1 ,699 .10 30 H20 76 ,938 2 ,564.60 MPF-848 10/1/2009 1,463.60 31 H20 60,362 1,947.16 MPF-848 11/1/2009 1,434.50 30 H20 67,827 2,260.90 MPF-848 12 /1/2009 1 ,724.20 31 H20 90,996 2,935.35 MPF-85 1 /1 /2009 2 ,745 .70 21 H20 34,083 1 ,623 MPF-85 1/1/2009 4 ,373.40 9 GAS 17,900 1,988.89 MPF-85 2/1/2009 2 ,849 18 H20 26,518 1,473.22 MPF-85 3/1/2009 2,212.20 10 H20 13,376 1,337.60 MPF-85 4/1/2009 2,429 .70 30 H20 39 ,385 1,312.83 MPF-85 5/1/2009 2 ,283 .40 27 H20 34 ,974 1,295 .33 MPF-85 6/1/2009 2 ,631.60 25 H20 38,859 1,554.36 MPF-85 7/1/2009 2,631.10 20 H20 32,142 1 ,6 07 .10 MPF-85 8/1/2009 2,699.70 31 H20 46,088 1,486.71 MPF-85 9/1/2009 2,770 .70 30 H20 43,765 1,458 .83 MPF-85 10/1/2009 2,879 .20 31 H20 47 ,176 1,521 .81 MPF-85 11/1/2009 2 ,969.20 30 H20 45,612 1,520.40 MPF-85 12/1 /2009 3,046 .90 31 H20 46,604 1,503.35 MPF-88 1 /1 /2009 1,774.50 6 H20 17,336 2,889 .33 MPF-88 2/1/2009 1,482 .50 28 H20 81 ,589 2,913 .89 MPF-88 3/1/2009 1 ,794 .90 31 H20 93,441 3,014.23 MPF-88 4/1/2009 1,877.80 30 H20 90,776 3,025.87 MPF-88 5/1/2009 1 ,945.70 31 H20 95,793 3 ,090.10 MPF-88 6/1/2009 1,899 .70 27 H20 81,221 3,008 .19 MPF-88 7/1/2009 1 , 174.40 16 H20 22 ,668 1,416 .75 MPF-88 8/1/2009 1 ,383 31 H20 87 ,674 2,828 .19 MPF-88 9/1/2009 1,410.60 30 H20 73 ,533 2,451.10 MPF-88 10/1/2009 1,487.30 31 H20 84,007 2,709.90 MPF-88 11/1 /2009 1 ,515.90 30 H20 82,556 2,751.87 MPF-88 12/1/2009 1 ,642 .80 31 H20 92,907 2,997 MPF-89 1 /1 /2009 2 ,948 .30 31 H20 50 ,868 1,640.90 MPF-89 2/1/2009 3 ,020 .10 28 H20 44,314 1,582 .64 MPF-89 3/1/2009 3 ,040.20 31 H20 47,693 1,538.48 MPF-89 4/1/2009 3,049.10 30 H20 45,741 1,524 .70 MPF-89 5/1/2009 3,063 .10 31 H20 46 ,788 1,509 .29 MPF-89 6/1/2009 3 ,086 .90 18 H20 29 ,149 1,619 .39 MPF-89 7/1/2009 303 1 H20 318 3 18 MPF-89 8/1/2009 2,479 .20 31 H20 33 ,910 1,093 .87 MPF-89 9/1/2009 2,738 .20 30 H20 33,740 1, 124 .67 MPF-89 10/1/2009 3 ,010.50 31 H20 41 ,764 1,347.23 MPF-89 11 /1 /2009 4 ,754.40 4 GAS 1,734 433 .5 MPF-89 11 /1 /2009 3 , 163.40 27 H20 35,529 1,315.89 MPF-89 12/1/2009 2 ,994.10 21 GAS 1, 130 53 .80952 MPF-89 12 /1/2009 3,055.50 11 H20 16,543 1,503.91 MPF-90 1/1/2009 0 H20 0 MPF-90 2/1/2009 0 H20 0 MPF-90 3/1/2009 0 H20 0 MPF-90 4/1/2009 0 H20 0 MPF-90 5/1/2009 0 H20 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPF-90 6/1/2009 0 H20 0 MPF-90 7/1/2009 0 H20 0 MPF-90 8/1/2009 0 H20 0 MPF-90 9/1/2009 0 H20 0 MPF-90 10/1 /2009 0 H20 0 MPF-90 11 /1 /2009 0 H20 0 MPF-90 12/1 /2009 0 H20 0 MPF-91 1/1/2009 2,409.40 31 H20 46 ,244 1,491 .74 MPF-91 2/1/2009 2,396.60 28 H20 42 ,154 1,505 .50 MPF-91 3/1/2009 2,392 .90 31 H20 47 ,516 1,532 .77 MPF-91 4/1/2009 2,437 .80 14 H20 20,356 1,454 MPF-91 4/1/2009 3,863.30 17 GAS 38,978 2,292 .82 MPF-91 5/1/2009 3,242.90 14 GAS 31, 117 2,222.64 MPF-91 6/1/2009 3,452 .50 29 GAS 58 ,279 2,009 .62 MPF-91 7/1/2009 3,326 .10 31 GAS 44,555 1,437.26 MPF-91 8/1/2009 3,251.10 31 GAS 49 ,916 1,610 .19 MPF-91 9/1/2009 2,088 14 H20 19 ,043 1 ,360 .21 MPF-91 9/1/2009 3,181.30 17 GAS 29 ,795 1,752 .65 MPF-91 10/1/2009 2 ,061 31 H20 40 ,948 1,320 .90 MPF-91 11/1/2009 1,913.10 30 H20 30,471 1 ,015 .70 MPF-91 12/1/2009 2 ,246.50 3 1 H20 46,838 1 ,510.90 MPF-92 1 /1 /2009 2,760 3 1 H20 47,460 1,530.97 MPF-92 2/1/2009 2,999 .90 28 H20 41,111 1,468.25 MPF-92 3/1/2009 3 ,026.60 31 H20 39,209 1,264.81 MPF-92 4/1/2009 2 ,964 30 H20 23,418 780 .6 MPF-92 5/1/2009 3 ,074.30 27 H20 32,526 1 ,204 .67 MPF-92 6/1/2009 2 ,299 7 H20 7 ,834 1,119.14 MPF-92 7/1/2009 2,428.60 20 H20 17,874 893 .7 MPF-92 8/1/2009 2 ,738.10 31 H20 31 ,551 1,017.77 MPF-92 9/1/2009 4,661.50 14 GAS 4,360 311.42857 MPF-92 9/1/2009 2,896.50 17 H20 14 ,240 837 .64706 MPF-92 10 /1/2009 4,582 3 1 GAS 30,940 998.06452 MPF-92 11 /1 /2009 4,618.20 30 GAS 35,33 1 1 ,177.70 MPF-92 12/1/2009 1,798 1 GAS 104 104 MPF-92 12/1 /2009 2 ,854 27 H20 21 ,682 803 .03704 MPF-95 1 /1 /2009 2,468.50 31 H20 64,470 2,079.68 MPF-95 2/1 /2009 2 ,504.70 28 H20 56 ,203 2,007.25 MPF-95 3/1/2009 2 ,527 .60 31 H20 63 ,759 2 ,056 .74 MPF-95 4/1 /2009 2 ,031 .70 14 H20 25 ,087 1 ,791.93 MPF-95 5/1 /2009 2 ,279 .90 21 H20 39, 122 1 ,862.95 MPF-95 6/1/2009 1,605 .90 19 H20 35 ,531 1 ,870.05 MPF-95 7/1/2009 1,990.50 20 H20 38 , 167 1 ,908.35 MPF-95 8/1/2009 2 ,078.30 3 1 H20 54,540 1 ,759.35 MPF-95 9/1/2009 2 ,190 .90 30 H20 54,089 1 ,802 .97 MPF-95 10/1/2009 2 ,068 31 H20 41,413 1 ,335.90 MPF-95 11/1/2009 1,999 30 H20 48 , 136 1,604.53 MPF-95 12/1 /2009 1 ,742.90 21 H20 15 ,593 742.52381 MPF-99 1/1/2009 3, 189 .10 3 1 H20 26,319 849 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPF-99 2/1/2009 3,266 28 H20 24,697 882.03571 MPF-99 3/1/2009 3,344.40 31 H20 28, 162 908.45161 MPF-99 4/1/2009 3,383.70 30 H20 27,402 913.4 MPF-99 5/1/2009 3,400 .80 31 H20 28,245 911.12903 MPF-99 6/1/2009 3,124 24 H20 20,378 849.08333 MPF-99 7/1/2009 2,579 .70 20 H20 14 , 113 705.65 MPF-99 8/1/2009 2,887.60 31 H20 24 ,558 792.19355 MPF-99 9/1/2009 2 ,963.40 30 H20 23 ,735 791.16667 MPF-99 10/1/2009 3 ,091 31 H20 26 ,493 854 .6129 MPF-99 11/1 /2009 3 ,051.20 30 H20 24 ,274 809.13333 MPF-99 12/1 /2009 3,292.70 31 H20 28,640 923.87097 MPH-06 1 /1 /2 009 0 H20 0 MPH-06 2/1/2009 0 H20 0 MPH-06 3/1/2009 0 H20 0 MPH-06 4/1/2009 0 H20 0 MPH-06 5/1/2009 0 H20 0 MPH-06 6/1/2009 0 H20 0 MPH-06 7/1/2009 0 H20 0 MPH-06 8/1/2009 894.4 19 H20 5,650 297.36842 MPH-06 9/1/2009 1,020.70 30 H20 11 ,050 368.33333 MPH-06 10/1/2009 1 ,998 .50 31 H20 71 ,649 2,311.26 MPH-06 11 /1/2009 1 ,97 1.70 30 H20 70,644 2,354.80 MPH-06 12 /1/2009 2,030.30 31 H20 78, 180 2,521 .94 MPJ-11 1/1 /2009 2,077.80 31 H20 30,088 970.58065 MPJ-11 2/1/2009 2,020.40 28 H20 28,092 1,003 .29 MPJ-11 3/1/2009 2,030.60 31 H20 31,540 1,017.42 MPJ-11 4/1/2009 2,022 .30 30 H20 32,445 1,081.50 MPJ-11 5/1/2009 2,052.80 31 H20 31,120 1,003.87 MPJ-11 6/1/2009 2,040.70 30 H20 29 ,448 981.6 MPJ-11 7/1/2009 2,018 .10 23 H20 24 ,660 1,072.17 MPJ -11 8/1/2009 2,242 .10 31 H20 49,826 1,607.29 MPJ-11 9/1/2009 2,200 .30 30 H20 37 ,072 1,235.73 MPJ-11 10/1 /2009 2, 172.40 31 H20 36,093 1,164.29 MPJ-11 11 /1 /2009 2,187.50 30 H20 38,659 1,288 .63 MPJ -11 12 /1 /2009 2,271.60 31 H20 47,893 1,544.94 MPJ-13 1 /1 /2009 1,913 31 H20 33,291 1 ,073 .90 MPJ-13 2/1 /2009 1,886.10 28 H20 26 ,279 938.53571 MPJ-13 3/1/2009 1,968.30 31 H20 35,852 1,156.52 MPJ-13 4/1/2009 1,929.50 30 H20 32 ,517 1 ,083.90 MPJ-13 5/1 /2009 1,931.10 31 H20 32 ,688 1,054.45 MPJ-13 6/1/2009 1 ,953 .90 30 H20 31 ,302 1,043.40 MPJ-13 7/1/2009 1 ,911.80 24 H20 26,232 1 ,093 MPJ-13 8/1/2009 1,828.40 30 H20 28,959 965.3 MPJ-13 9/1/2009 1,892.20 30 H20 41,977 1,399.23 MPJ-13 10/1 /2009 1,896 .70 31 H20 39 ,768 1,282.84 MPJ-13 11 /1 /2009 1,930 .70 30 H20 42 , 113 1,403 .77 MPJ-13 12/1 /2009 1,866.40 18 H20 20 ,878 1,159 .89 MPJ-16 1/1/2009 0 H20 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPJ-16 2/1/2009 0 H20 0 MPJ-16 3/1/2009 0 H20 0 MPJ-16 4/1/2009 0 H20 0 MPJ-16 5/1/2009 0 H20 0 MPJ-16 6/1 /2009 0 H20 0 MPJ-16 7/1/2009 0 H20 0 MPJ-16 8/1/2009 0 H20 0 MPJ-16 9/1/2009 0 H20 0 MPJ-16 10/1 /2009 0 H20 0 MPJ-16 11/1 /2009 0 H20 0 MPJ-16 12/1/2009 0 H20 0 MPK-18A 1/1/2009 0 H20 0 MPK-18A 2/1/2009 0 H20 0 MPK-18A 3/1 /2009 0 H20 0 MPK-18A 4 /1/2009 0 H20 0 MPK-18A 5/1/2009 0 H20 0 MPK-18A 6/1 /2009 0 H20 0 MPK-18A 7/1/2009 0 H20 0 MPK-18A 8/1/2009 0 H20 0 MPK-18A 9/1 /2009 0 H20 0 MPK-18A 10/1/2009 0 H20 0 MPK-18A 11 /1 /2009 0 H20 0 MPK-18A 12/1/2009 0 H20 0 MPK-21A 1 /1 /2009 0 H20 0 MPK-21A 2/1 /2009 0 H20 0 MPK-21A 3/1/2009 0 H20 0 MPK-21A 4/1/2009 0 H20 0 MPK-21A 5/1/2009 0 H20 0 MPK-21A 6/1 /2009 0 H20 0 MPK-2 1A 7/1/2009 0 H20 0 MPK-21A 8/1/2009 0 H20 0 MPK-21A 9/1/2009 0 H20 0 MPK-21A 10/1/2009 0 H20 0 MPK-21A 11 /1 /2009 0 H20 0 MPK-21A 12 /1 /2009 0 H20 0 MPK-22 1 /1 /2009 0 H20 0 MPK-22 2/1/2009 0 H20 0 MPK-22 3/1/2009 0 H20 0 MPK-22 4/1 /2009 0 H20 0 MPK-22 5/1 /2009 0 H20 0 MPK-22 6/1/2009 0 H20 0 MPK-22 7/1/2009 0 H20 0 MPK-22 8/1/2009 0 H20 0 MPK-22 9/1/2009 0 H20 0 MPK-22 10/1/2009 0 H20 0 MPK-22 11 /1 /2009 0 H20 0 MPK-22 12/1/2009 0 H20 0 MPK-43A 1 /1 /2009 0 H20 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPK-43A 2/1/2009 0 H20 0 MPK-43A 3/1/2009 0 H20 0 MPK-43A 4/1/2009 0 H20 0 MPK-43A 5/1/2009 0 H20 0 MPK-43A 6/1/2009 0 H20 0 MPK-43A 7/1/2009 0 H20 0 MPK-43A 8/1/2009 0 H20 0 MPK-43A 9/1/2009 0 H20 0 MPK-43A 10/1/2009 0 H20 0 MPK-43A 11 /1 /2009 0 H20 0 MPK-43A 12/1/2009 0 H20 0 MPL-08 1/1/2009 2,736.10 31 H20 36,308 1, 171.23 MPL-08 2/1/2009 2,945.30 28 H20 31,641 1, 130.04 MPL-08 3/1/2009 2,917.20 31 H20 37,071 1,195.84 MPL-08 4/1/2009 2 ,987 .80 30 H20 36,245 1,208.17 MPL-08 5/1/2009 3 ,011.60 31 H20 37,445 1 ,207.90 MPL-08 6/1/2009 2 ,951.30 24 H20 31,039 1,293.29 MPL-08 7/1 /2009 2,794 .70 20 H20 25,202 1 ,260 .10 MPL-08 8/1/2009 2,895.40 31 H20 33,018 1 ,065 .10 MPL-08 9/1/2009 2 ,937.30 30 H20 31,109 1 ,036 .97 MPL-08 10/1/2009 3 ,036 .20 31 H20 35 ,582 1,147.81 MPL-08 11/1/2009 3,052.60 30 H20 33,411 1 ,113.70 MPL-08 12/1/2009 3,037 .80 6 H20 5,509 918.16667 MPL-09 1 /1 /2009 0 H20 0 MPL-09 2/1/2009 0 H20 0 MPL-09 3/1/2009 1 ,940 28 H20 41,764 1,491.57 MPL-09 4/1/2009 2 ,384 .80 30 H20 51, 156 1,705.20 MPL-09 5/1/2009 2,472.30 31 H20 49,734 1 ,604.32 MPL-09 6/1/2009 2,537.20 16 H20 28,093 1,755 .8 1 MPL-09 7/1/2009 0 H20 0 MPL-09 8/1/2009 1,768.30 19 H20 18,598 978.84211 MPL-09 9/1/2009 1,938.90 26 H20 30,739 1,182.27 MPL-09 10/1/2009 2,649.70 31 H20 64, 197 2,070.87 MPL-09 11 /1 /2009 2,871.50 11 H20 25,051 2,277.36 MPL-09 12/1/2009 0 H20 0 MPL-10 1 /1/2009 0 H20 0 MPL-10 2/1/2009 0 H20 0 MPL-10 3/1/2009 0 H20 0 MPL-10 4/1/2009 0 H20 0 MPL-10 5/1/2009 0 H20 0 MPL-10 6/1/2009 0 H20 0 MPL-10 7/1/2009 0 H20 0 MPL-10 8/1/2009 0 H20 0 MPL-10 9/1/2009 0 H20 0 MPL-10 10 /1/2009 0 H20 0 MPL-10 11 /1 /2009 0 H20 0 MPL-10 12/1/2009 0 H20 0 MPL-15 1/1/2009 2,498.80 13 H20 13,412 1,031.69 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPL-15 2/1/2009 2 ,251 .50 4 H20 8 ,764 2 , 191 MPL-15 3/1/2009 2 ,835 .30 31 H20 80,917 2,610.23 MPL-15 4/1/2009 3,038 .70 30 H20 75 ,065 2,502.17 MPL-15 5/1/2009 3,192 31 H20 86 ,349 2 ,785.45 MPL-15 6/1/2009 3,047 27 H20 67,210 2,489 .26 MPL-15 7/1/2009 2 ,692 .70 20 H20 33,329 1,666.45 MPL-15 8/1/2009 2,350.90 31 H20 23 ,061 743.90323 MPL-15 9/1/2009 2,224.10 19 H20 23 ,929 1,259.42 MPL-15 10/1/2009 2,964.80 31 H20 83 ,697 2 ,699.90 MPL-15 11 /1 /2009 3 ,095.70 30 H20 78,701 2,623 .37 MPL-15 12/1 /2009 3,152.80 28 H20 71 ,090 2,538 .93 MPL-16A 1 /1 /2009 1 ,513 .60 31 H20 60 ,573 1 ,953 .97 MPL-16A 2/1/2009 1,681 .60 26 H20 53 ,401 2,053 .88 MPL-16A 3/1/2009 1,366 14 H20 28 ,557 2,039 .79 MPL-16A 4/1/2009 1,799.90 13 H20 30 , 110 2 ,316 .15 MPL-16A 4/1 /2009 3,214.60 18 GAS 37 , 137 2 ,063 .17 MPL-16A 5/1/2009 1 ,627.50 5 H20 3 ,885 777 MPL-16A 5/1/2009 3,075.40 27 GAS 58 , 170 2 , 154.44 MPL-16A 6/1/2009 1,134.80 4 H20 3,164 791 MPL-16A 7/1/2009 0 H20 0 MPL-16A 8/1/2009 0 H20 0 MPL-16A 9/1/2009 916 .9 18 H20 37 ,840 2,102 .22 MPL-16A 10/1/2009 1,051.70 31 H20 64 , 179 2,070 .29 MPL-16A 11 /1 /2009 1,385.80 30 H20 71 ,603 2,386.77 MPL-16A 12/1 /2009 1,620.30 28 H20 76 ,004 2 ,714.43 MPL-21 1/1 /2009 0 GAS 0 MPL-21 2/1/2009 0 GAS 0 MPL-21 3/1/2009 0 GAS 0 MPL-21 4/1/2009 0 GAS 0 MPL-21 5/1 /2009 0 GAS 0 MPL-21 6/1 /2009 0 GAS 0 MPL-21 7/1 /2009 0 GAS 0 MPL-21 8/1 /2009 0 GAS 0 MPL-21 9/1/2009 0 GAS 0 MPL-21 10 /1/2009 0 GAS 0 MPL-21 11 /1 /2009 0 GAS 0 MPL-21 12 /1 /2009 0 GAS 0 MPL-24 1/1/2009 2 ,635.10 3 1 H20 3 3 ,549 1 ,082 .23 MPL-24 2/1/2009 2 ,896.80 19 H20 21 ,645 1,139 .21 MPL-24 3/1/2009 3 ,981 .10 3 GAS 3 ,461 1 ,153.67 MPL-24 4/1/2009 4 ,195 30 GAS 52 ,870 1 ,762 .33 MPL-24 5/1/2009 4 ,125.20 18 GAS 31 ,8 95 1,771.94 MPL-24 6/1/2009 0 GAS 0 MPL-24 7/1 /2009 0 GAS 0 MPL-24 8/1/2009 1,897 .60 20 H20 23 ,081 1 ,154.05 MPL-24 9/1/2009 2 ,205 .30 30 H20 34 ,209 1 ,140 .30 MPL-24 10 /1/2009 2 ,595.80 31 H20 43,109 1 ,390 .61 MPL-24 11 /1/2009 2 ,692.10 30 H20 41 ,155 1,371 .83 Exhibit 2-G Injection Rate and Pressu re Data Milne Point Field Kuparuk River Pool Wellhead Days ln j Vol Alloc Injection Rate Sw Na me Mont h Pres Avg (psi) Operating Prod uct Code (BBL, MCF) (BBL , MCF) M PL-24 12/1 /2009 2,761.50 28 H2 0 35,316 1 ,26 1.29 M PL-32 1/1/2009 3,387.60 3 1 H2 0 46,242 1 ,491 .68 M PL-32 2/1/2009 3,550.90 28 H2 0 36,8 75 1 ,3 16.96 M PL-32 3/1/2009 3,407.10 31 H2 0 4 1,4 13 1 ,335 .90 M PL-32 4/1/2009 3,442.70 30 H2 0 39 ,309 1 ,3 10.30 M PL -32 5/1/2009 4,672.90 26 GAS 10,491 403 .5 M PL -32 5/1/2009 3,5 19.50 6 H2 0 7 ,153 1,192 .17 MPL-32 6/1/2009 4,43 1.80 30 GAS 31 ,580 1,052.67 MPL-32 7/1/2009 3,084.40 31 GAS 17 ,628 568 .64516 MPL-32 8/1/2009 2,85 1 .90 9 H2 0 12 ,844 1,42 7.11 MPL-32 8/1/2009 2,700 .10 23 GAS 29 ,239 1,271 .26 MPL-32 9/1/2009 3,12 7 .2 0 30 H2 0 46,920 1 ,564 MPL-32 10/1/2009 3,330 29 H2 0 45,69 7 1 ,5 75.76 MPL-32 11 /1 /2009 3,349.40 30 H2 0 43 ,858 1 ,461 .93 MPL -32 12/1/2009 3,334.40 28 H2 0 43 ,639 1,558 .54 MPL-33 1/1/2009 3,361 .60 31 H2 0 149,68 7 4,828.61 M PL-33 2/1/2009 3,451 .60 28 H2 0 126,422 4,5 15.07 M PL-33 3/1/2009 3,376 .50 31 H2 0 15 1,065 4,873 .06 M PL-33 4 /1/2009 3,4 15.4 0 30 H2 0 145 ,874 4 ,862.47 M PL-33 5/1/2 00 9 3,426.6 0 3 1 H2 0 154,466 4 ,982.77 M PL -33 6/1/2009 3,0 74.2 0 25 H2 0 104,994 4,199 .7 6 M PL -33 7/1/2009 3,177 19 H2 0 106,880 5,625 .26 M PL-33 8/1/2 0 09 3 ,284 .9 0 3 1 H2 0 173,595 5 ,599 .84 M PL -33 9/1/2009 2 ,886 28 H2 0 105,99 1 3 ,785 .39 M PL-33 10/1/2009 3,210 .10 31 H2 0 147,09 7 4 ,745 .06 M PL -33 11 /1 /2009 3,282 30 H2 0 146,055 4 ,868 .50 M PL -33 12/1 /2009 3 ,288.70 28 H2 0 131,295 4 ,689.11 M PL -34 1/1/2009 0 H2 0 0 M PL -34 2/1/2009 0 H2 0 0 M PL -34 3/1/2009 0 H2 0 0 M PL -34 4/1/2009 0 H2 0 0 M PL -34 5/1/2009 0 H2 0 0 M PL -34 6/1/2009 0 H2 0 0 M PL -34 7/1/2009 0 H2 0 0 M PL -34 8/1/2009 0 H2 0 0 M PL -34 9/1/2009 0 H2 0 0 M PL -34 10/1/2009 0 H2 0 0 M PL-34 11 /1 /2009 0 H2 0 0 M PL-34 12/1/2009 0 H2 0 0 M PL -39 1/1/2009 0 H2 0 0 M PL -39 2/1 /2009 0 H2 0 0 M PL -39 3/1/2009 0 H2 0 0 M PL -39 4/1/2009 0 H2 0 0 M PL-39 5/1/2009 0 H2 0 0 M PL -39 6/1/2009 0 H2 0 0 M PL -39 7/1/2009 0 H2 0 0 M PL -39 8/1/2009 0 H2 0 0 M PL -39 9/1 /2009 0 H2 0 0 Exhibit 2-G Injection Rate and Pressure Data Milne Point Field Kuparuk River Pool Wellhead Days lnj Vol Alloc Injection Rate Sw Name Month Pres Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPL-3 9 10/1/2009 0 H20 0 MPL-39 11 /1/2009 0 H20 0 MPL-3 9 12/1/2009 0 H2 0 0 MPL-42 1/1/2009 0 GAS 0 MPL-42 2/1 /2009 0 GAS 0 MPL-42 3/1/2009 0 GAS 0 MPL-42 4/1/2009 0 GAS 0 MPL-42 5/1/2009 0 GAS 0 MPL-42 6/1/2009 0 GAS 0 MPL-42 7/1/2009 0 GAS 0 MPL-42 8/1/2009 0 GAS 0 MPL-42 9/1 /2009 0 GAS 0 MPL-42 10 /1/2009 0 GAS 0 MPL-42 11 /1/2009 0 GAS 0 MPL-42 12 /1/2009 0 GAS 0 Waterflood Pattern Map Section 3 Schrader Bluff Oil Pool List of Exhibits Total Reservoir Production Plot Total Reservoir Injection Plot Pertinent Data Summary Reservoir Voidage Balance Static Pressure Data Injection Rate & Pressure Data By Well Daily Allocation Factors 3-A 3-B 3-C 3-D 3-E 3-F 3-G 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 production and injection well pairings are shown to give a general visualization of waterflood polygons, but do not show estimated waterflood sweep. There were 54 producing wells and 42 injection wells active during 2009.1 A WAG pilot was conducted in the Schrader Bluff in 2008 utilizing 2 injectors. Exhibit 3-B shows a production plot for the Schrader Bluff reservoir covering the entire project history through December 2009. The Schrader Bluff Oil Pool oil production averaged 9.1 MSTBD for 2009 compared to 12.0 MSTBD in 2008. This represents an oil production decrease of 32% in 2009. The 2009 production decrease can be largely attributed to the natural fieldwide decline coupled with the inability to sustain initial production rates in the LTSI producers that were brought on throughout 2008. 2009 gas production averaged 4.3 MMSCFD versus 6.7 MMSCFD in 2008. Water production averaged 17.0 MBWD in 2009 compared to 17.4 MBWD in 2008. Cumulative production since waterflood startup through the end of 2009 is 60.9 MMSTB of oil, 38.1 BSCF of gas, and 42.1 MMSTB of water. Exhibit 3-C shows an injection plot for the Schrader Bluff reservoir covering the entire project history through December 2009. The water injection rate averaged 36.3 MBWD for 2009. Water injection in 2008 also averaged 36.3 MBWD. This represents a consistent water injection rate from 2008 to 2009. Cumulative water injection since waterflood startup through the end of 2009 is 115.0 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. The average gas injection rate in 2008 was 258 MSCFD. Cumulative gas injection through the end of 2009 remains as it was at year-end 2008: 220 MMSCF. As of December 2009 the cumulative under injection is 33.6 MMRB. The high cumulative under-injection in the Schrader Bluff reservoir is due to several factors: • Pre-production of early development wells • Economic constraints on drilling injection wells in the smaller hydraulic units • Occurrence of Matrix Bypass Events leading to reductions in the number of usable injection & offtake points In the supported water flood patterns, under-injection is minimal. The average voidage replacement ratio, or VRR, for 2009 was 1.18, which is an increase compared to the 2008 VRR of 1.00. The RWO that began in December of 2009 to convert MPJ-19 to injection also increases injection capacity, but as the well did not see injection rate in that year, it will not be included in the 2009 report. 1 Note that the count of 42 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 55 active injectors. Water cut increased from 59.2% in 2008 to 65.1 % in 2009. The increase can be attributed to waterflood maturation and the absence of drilling in 2009. GOR decreased from 558 SCF/STB in 2008 to 472 SCF/STB in 2009. Exhibit 3-D is a summary of the pertinent production information for the Schrader Bluff Oil Pool in 2009. 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 2009. In 2009, 69 pressures were obtained in Schrader Bluff wells, 10 pressures were obtained in injectors and 59 pressures were obtained in 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 2009. As the Milne Schrader reservoir shares surface flowlines and its processing facility with the Milne Kuparuk, Sag, and U gnu 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 2009 was 0.89. This is an improvement from the 2008 average of 0.84, mostly due to a change in metering at the field's largest producing pad. For reference, the allocation factor through the first half of the year was 0.81, a continuation of the deteriorating quality of allocations seen in recent history at Milne Point. The largest cause of this deterioration was found through extensive investigation and testing to be the watercut meter at MPF-Pad. Studies and tests were conducted to diagnose the issue and multiple remediation strategies were implemented. A new meter was installed and put into service at MPF-Pad early in 2009, and after a trial period and confirmative tests, it became the approved metering device for that pad as of July 1, 2009. This led to an improvement of field oil allocation factor to 0.96 for the second half of 2009. For 2009, the water allocation factor averaged 1.26, and the gas allocation factor was 1.05. The water allocation factor improved over the 2008 average of 1.32 while the gas allocation factor worsened compared to 2008's average of 1.00 . 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. bp N l 1 Exhibit 3-A 2009 Schrader Bluff Formation Waterflood Pattern Map Milne Point Unit HU _U • MPl.·45 II MPJ..18 SBF Waterflood Polygons ~ SBF-N ['.;§fil, @ J SBF-0 0 1 HU _S 2 HU _1 4 ~ ):" >< <C c--m m I- I-CJ) CJ) --a:I m I-I-CJ) CJ) == == ~ ~ c c 0 0 .. ·-u ti :J :J "C "C 0 0 .. .. 11. 11. .. -Q) o~ Exhibit 3-8 BP ALASKA -Milne Point Unit Schrader Reservoir, Total Production 100000 100000 10000 10000 1000 1000 100 10 -+I 10 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 -oil Prod Cum SCH ~Water Prod Rate SCH -Gas Prod Cum SCH -Oil Prod Rate SCH -water Prod Cum SCH --e--Gas Prod Rate SCH 80 1.2 70 Q) = 60 ..J c I · I I · · 1 I I I I 1 I I !! I I ·· I I I • "-1-1·0 0 I I I I I ¥ I I 1 I I I w'lAQ. L L~H 1'f . I •.-..1 t o.8 I!! 50 :J · ···· ···· ·· ··· .,. · 41H .. 8 3 1 ~'~Q ~::==c ~~==~~::~ Gi 'lii 20 3:: 10 ISI. -l..ftJ.l,,-.,i, I I . I I I I I l I I l I I + 0.2 0 M ~ ~ ~ ~ % % ~ oo ~ oo ~ m m M m oo ITT oo oo [=!=w8ier-c~l %sc ti_----.--Pr0ciucer5 Online --*"""Gas/Oil Ratio scH I ):" < Q Li:: 0 CJ) == u: 0 CJ) == :§. c 0 .. u :J "C 0 .. 11. Ill IU CJ 2009 production_injection.xls 3/24/2010 ~> > <( <( c e u: mo I-(/) ~ == m . I-LL (/) 0 == (/) -== c: == o-; c (J 0 Q) ·-·c ti -Q) ... ·- Q) -= 'lii"' == ~ 1000000 100000 10000 1000 100 10 45 40 35 Q) 30 c: :::i c: 0 25 "' ... 0 "2 20 :E "*' 15 10 5 0 If -~ -· -~ ---1; r Exhibit 3-C BP ALASKA -Milne Point Unit Schrader Reservoir, Injection .. .... ... .. . ... .. --... r · .. .. , ~ .;lifli" ~ ~ . ~ -11 . ...... .... .. _..__ ~ -...,.,.. JI .. 'lT -- '·' ,_ v " ~ <t ' -J .. 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 I-water lnj Cum SCH -water lnj Rate SCH -Gas lnj Cum SCH ~Gas lnj Rate SCH I ' ........ ·' .. :-.. ~·~ ~· • 4 • ~ ,..~ • • ' :,C .... ·~ ~~ • ~ • • . . c . ' . ~ ~ ~ ""' ~ ·-* • , --.... V'f f\ • 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 ------------------~ I • Water Injectors Online --Gas Injectors Online 2009 production_injection.xls 3/24/2010 Exhibit 3-D Milne Point Unit -Schrader Bluff Oil Pool SUMMARY OF PERTINENT DATA As of December 31, 2009 WATERFLOOD START-UP DATE: PRODUCTION Prior to Waterflood Start-Up: Oil (MSTB) Gas (MMSCF) Water (MSTB) Since Waterflood Start-Up: Oil (MSTB) Gas (MMSCF) Water (MSTB) FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB) Injection Gas (MMSCF) AVERAGE OF PRESSURES OBTAINED IN 2009@4,000' TVD ss December , 2009 Pressure (psig) WELL COUNT (Wells in Operation)* Production Wells WAG Injection Water Only Injection Gas Only Injection Notes: * Reflects ONLY operating wells March 1992 902 303 136 60,039 37.790 41 ,977 115,000 220 1,522 54 0 42 0 Exhibit 3-E Production: Oil Water Month Prod Rate Prod Rate (stb/day) (stb/day) 1/31/2009 9623 17611 212812009 9467 18643 3/31/2009 8962 20887 4/30/2009 9004 17925 5/31/2009 8753 17890 6/30/2009 8387 17150 7/31/2009 6967 13300 8/31/2009 8608 13332 9/30/2009 9910 16736 10/31/2009 9768 18076 11/30/2009 10032 17462 12/31 /2009 9707 15308 Average : 2009 9 ,099 17,027 Cumulative : mstb mstb 31-Dec-09 60,941 42.113 RESERVOIR VOIDAGE BALANCE January -December 2009 Injection: Gas Reservoir Water Gas Prod Rate Voidage lnj Rate lnj Rate (mscf/day) (rbbVday) (stb/day) (mscf/day) 7019 36,390 35196 0 5750 35,274 41115 0 5023 35,988 42685 0 3905 31,231 40967 0 3502 30,355 37422 0 3133 28,737 37270 0 2Tl5 23,193 30356 0 3258 25,250 37038 0 4681 31 ,965 34169 0 4430 32 ,808 34570 0 4218 32 ,048 33493 0 4500 30,078 31446 0 4,349 31 ,110 36 ,310 0 mmscf mrb mstb mmscf 38,093 150,126 115,000 220 Page I Voidage Replacement (rbbVday) 35 ,548 41 ,526 43,112 41 ,376 37,796 37 ,643 30 ,660 37,408 34,510 34 ,915 33,828 31 ,760 36 ,674 mrb 116,503 Milne Point Unit Schrader Bluff Oil Pool Voidage Voidage Replacement Balance Ratio (rbbVday) 0 .98 -842 1.18 6 ,252 1.20 7 ,124 1.32 10,145 1.25 7 ,441 1.31 8 ,906 1.32 7,467 1.48 12,158 1.08 2 ,545 1.06 2 ,108 1.06 1,780 1.06 1,682 1.18 5 ,564 mrb 0.78 -33 ,623 Exhibit 3-F Static Pressure Data Schrader Bluff Pool STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: BPXA 2. Address: 900 E. Benson Blvd Anchorage, Alaska 99508-4254 3. Unit or Lease Name: Milne Point 4. Field and Pool: Schrader Bluff Pool 5. Datum Reference: 4000' SS 6. Oil Gravity: API = 14 -22 7. Gas Gravity: Air= 0.65 8. Well Name and 9. AP I Number 50 10. Oil (0) or Gas 11. AOGCC 12. Final Test 13. Shut-In 14. Press. Surv. 15. B.H. 16. Depth 17 . Final 18. Datum 19 . Pressure 20. Comments Zone Number: XXX-XXXXX -XX-XX (G) Pool Code Date Time, Hours Type (see Temp. Tool TVDss Pressure at TVDss Gradient, psi/ft. Pressure at instructions for Too l Depth (input) Datum (cal) codes) MPC-41 50-500-29230-1 4-00 PROD 525140 11/8/2009 224 pp 4, 132.96 1,500 4,000 0.444 1,441 Was gaining 1 psi/day for a OA MPE-12 50-500-29232-62-00 IN J 525140 12/9/2009 20.05 SBHP 84 4,324.27 2,646 4,000 0.400 2,516.29 NC+ND MPE -15 50-500-29225-28-00 PROD 525140 7/29/2009 1,664.85 SBHP 92 4,018.89 1,432 4,000 0.356 1,425.27 NB+NC+OA MPE-15 50-500-29225-28-00 PROD 525140 12/30/2009 5,355.73 SBHP 87 4,017.99 1,467 4,000 0.366 1,460.4 1 SBHP for RWO NB+NC+OA MPE-20A 50-500-29225-61-01 PROD 525140 2/25/2009 6,207 SBHP 83 3,900 .05 1,743 4,000 0.040 1,747 grad = 0.040 psi /ft NB+OA MPE-20A 50-500-29225-61-01 PROD 525140 3/8/2009 6477 pp 85.8 4,167.16 1,732 4,000 0.443 1,658 Was still gaining NB+OA MPE-24A 50-500-29228-67-01 PROD 525140 11 /20/2009 84 pp 85.5 4,161.66 1,234 4,000 0.396 1,170 Opportunistic pressure due OA+OB MP E-25A 50-500-29229-80-01 INJ 525140 11 /24/2009 487.5 SBHP 75 3,907.19 2,951 4,000 0.445 2,992.30 0.444 PSI /FT GRAD IENT OA+OB MPE-30A 50-500-29229-03-01 PROD 525140 6/8/2009 94 PP 4,245.13 1,532 4,000 0.441 1,424 Sti ll rapidly gaining OA MPG-02 50-500-29219-26-00 PROD 525140 7/26/2009 288 pp 3,697.33 1,006 4,000 0.443 1,140 Had flattened off N MPG-OBA 50-500-29221-41-01 PROD 525140 11/7/2009 10056 pp 3,331.02 1,570 4,000 0.439 1,864 Flattened out completely N+OA+OB MPG -1 0 50-500-29227-80-00 INJ 525140 7/24/2009 239.43 SBHP 80 3,914.64 2,300 4,000 0.425 2,336.29 NB+NC+OA+OB MPG-13 50-500-29227-82-00 INJ 525140 7/24/2009 247.77 SB HP 80 3,855.85 2,812 4,000 0.446 2,876.34 Th e !PROF of 6/3/2009 N+OA+OB MPG-14 50-500-29230-31-00 PROD 525140 7/26/2009 288 pp 3,849 .17 1,10 7 4,000 0.451 1,175 Sti ll climbing 8 psi/day N+OA+OB MPG-15 50-500-29227-84-00 PROD 525140 5/4/2009 888 pp 3,868.19 1,415 4,000 0.440 1,473 N+OA+OB MPG-15 50-500-29227-84-00 PROD 525140 7/27/2009 2,904 pp 3,868 .1 9 1,605 4,000 0.440 1,663 N+OA+OB MPG-16 50-500-29231 -89-00 PROD 525140 7/27/2009 3 12 pp 4,154.21 999 4,000 0.441 931 Still gaining 5 psi/day OA+OB MPG-18 50-500-29231-94-00 PROD 525140 7/26/2009 288 pp 4,022.26 1,136 4,000 0.449 1,126 Plug set in OB . Still gaining OA MP H-04 50-500-29220-64-00 PROD 525 140 1/24 /2009 2160 pp 83 3,52 1.05 1,564 4,000 0.430 1,770 Pump gauge doesn't work OA+OB+N MPH-07A 50 -500-29225-97-01 PROD 525 140 11 /7/2009 6600 pp 3,9 73.08 1,097 4,000 0.446 1,109 Completely flat OA+OB MPH-10 50-500-29227-95-00 PROD 525 140 8/10/2009 3240 pp 3,783.72 1,370 4,000 0.439 1,465 Gaining .5 psi/day N+OA+OB MPH-13A 50-500-29228-18-01 PROD 525140 10/12/2009 1632 pp 3,926.06 1,412 4,000 0.446 1,445 Very strange pressure N MPH-13A 50-500-29228-18-01 PROD 525140 10 /23/2009 1,896 SBHP 85 3,872.06 1,392 4,000 0.413 1,444.90 N MPH-16 50-500-29232-27-00 PROD 525140 7/28/2009 336 pp 3,863.03 1,165 4 ,000 0.445 1,226 OA+OB MPH-18 50-500-29232-24-00 PROD 525140 3/8/2009 923.55 SBHP 80 3,940.80 1,320 4,000 0.412 1,344.37 OA+OB MP H-19 50-500-29233-71-00 PROD 525140 5/15/2009 1152 pp 3,983.99 1,408 4 ,000 0.437 1,415 OA MPl-03 50-500 -29220-67-00 PROD 525140 3/28/2009 2,196 .7 2 SB HP 81 3,545.59 1,366 4,000 0.362 1,530.59 NA+NB+NC+NE+OA+OB MPl-04A 50-500-29220-68-01 PROD 525140 4/25/2009 1,272 PP 3,690 1,587 4,000 0.442 1,724 N+OA+OB MPl-04A 50-500-29220-68-01 PROD 525140 7/27/2009 3504 pp 3,690 1,607 4,000 0.439 1,743 Pump gauge stopped N+OA+OB MP l-04A 50-500-29220-68-01 PROD 525140 10/5/2009 5,192.58 SBHP 81 3,649 .89 1,621 4,000 0.401 1,76 1.40 N+OA+OB MPl-06 50-500-29228-22-00 PROD 525140 8/11/2009 1416 pp 3,655.02 1,572 4,000 0.441 1,724 VERY close relationship OA+OB MPl-06 50-500-29228-22-00 PROD 525140 10 /28/2009 1656 pp 3,655.02 1,633 4,000 0.441 1,785 VERY close relationship OA+OB MPl-07 50-500-29226-02-00 PROD 525140 7/27/2009 312 pp 3,483.48 1,300 4,000 0.445 1,530 OA+OB+N MPl-11 50-500-29230-33-00 PROD 525140 11 /7/2009 2136 pp 3,496.89 1,344 4,000 0.439 1,565 N+OA+OB MPl-1 3 50-500-29230-12-00 INJ 525140 10 /9/2009 SBHP 42 2,303.34 1,056 4,000 0.4 18 1,765.96 N MPl-14 50-500-29232-14-00 PROD 525 140 7/26/2009 288 pp 3,591.88 1,200 4,000 0.441 1,380 OA+OB+N MP l-15 50-500-29231 -06-00 PROD 525140 5/5/2009 1,944 PP 3,664.85 1,382 4 ,000 0.442 1,530 OA+OB MPl-15 50-500-29231 -06-00 PROD 525140 11 /7/2009 6384 pp 3,664.85 1,480 4,000 0.439 1,627 OA+OB MPl-16 50-500-29232-21-00 INJ 525140 6/1/2009 216 SBHP 98 3,857.81 2,420 4,000 0.985 2,560 OA MPl-16 50-500-29232-21-00 INJ 525140 6/1/2009 216 SBHP 100 3,715.99 2,498 4 ,000 0.187 2,4 45 N MPl-17 50-500-29232-12-00 PROD 525140 7/26/2009 288 pp 3,782.15 1,126 4,000 0.441 1,222 Still gaining 4 psi/day NB+OA+OB MPl-19 50-500-29232-18-00 PROD 525140 4/15/2009 2 ,6 16 pp 3,783.12 874 4,000 0.443 970 OB MP l-19 50-500-29232-18-00 PROD 525140 10/6/2009 6768 pp 3,783.12 878 4,000 0.443 97 4 Pump gauge stopped OB MPl-19 50 -500 -29232-18-00 PROD 525140 10/19/2009 7,09 7.05 SBHP 79 3,754 .08 1,072 4,000 0.373 1,163.84 OB MPJ-01A 50-500-29220-70-01 PROD 525140 7/27/2009 3 12 pp 3,279.66 888 4,000 0.441 1,206 OA+OB MPJ-03 50-500-29220-72-00 PROD 525140 7/25/2009 240 pp 3,567.76 1,498 4,000 0.442 1,689 N+OA+OB MPJ-05 50-500-29221-96-00 PROD 525140 7/27/2009 2184 pp 3,692.28 1,268 4,000 0.442 1,404 N+OA+OB MPJ-09A 50-500-29224-95-00 PROD 525140 4/15/2009 4080 pp 3,622.90 1,153 4,000 0.440 1,3 19 OA MPJ-09A 50-500-29224-95-01 PR O D 525140 11 /7/2009 9024 pp 3,622.90 1,200 4,000 0.440 1,366 Fl at pressure OA MPJ-19A 50-500-29226-07-01 PROD 525140 11 /29/2009 9175 pp 3,739.76 1,460 4,000 0.438 1,5 74 SI FOR CONV ER SION TO N+OA+OB M PJ-1 9A 50-500-29226-07-01 PROD 525140 12/11 /2009 9,463 .1 2 SBHP 8 1 3,7 13.55 1,347 4 ,000 0.175 1,397.05 N+OA+OB MPJ-23 50-500-29229-70-00 PROD 525140 8/23/2009 7008 pp 60 3,504 .7 0 1,475 4,000 0.440 1,693 from jet pump discharge OA+OB Exhibit 3-F Static Pressure Data Sc hrader Bl uff Poo l 8. Well Name and 9. API Number 50 10. Oil (0) or Gas 11. AOGCC 12. Final Test 13. Shut-In 14. Press. Surv. 15. B.H. 16. Depth 17. Fina l 18. Datum 19. Pressure 20. Comments Zone Number; XXX-XXXXX-XX-XX (G) Pool Code Date Tim e, Hours Type (see Temp. Tool TVDss Pressu re at TVDss Grad ient. ps i/ft. Pressure at instructi ons for Tool Depth (input) Datum (cal) codes) MPJ -26 50-500-29232 -05 -00 PRO D 525 140 51512009 816 pp 3 ,805.18 1,349 4,00 0 0.436 1,434 N+OA+OB MPJ-26 50-500 -29232 -05 -00 PRO D 525 140 9/18/2009 4056 pp 3,805.18 1,490 4,000 0.436 1,575 Very erra tic press ure trend. N+OA+OB MPS-02 50 -500 -2923 1-69-00 INJ 525 140 6/1/2009 2064 SB HP 98 4, 154.80 1,882 4,000 0.646 1,782 N, OA AN D OB we re open OB MPS-05 50-500 -2 9 23 1-00-00 PRO D 525 140 9/16/2009 110 4 pp 3,994.14 1,023 4,000 0.5 12 1,026 OA+O B MP S-08 50 -500 -29 23 1-68-00 PRO D 525 140 3/8/2009 720 SBHP 3,77 9.25 1,235 4,0 00 0.444 1,333 Las t day do w nh ole ga uge NB MP S-09 LS 50-500 -2 9 230-67-80 INJ 525 14 0 6/6/2009 5880 SBHP 79 4,048.33 1,737 4,0 00 0 .504 1,7 12.64 OB MPS-10A LS 50 -50 0-2 923 1-52 -0 1 INJ 525 140 5/13/2009 3 12 SBHP 87 4, 125 .0 0 1037 4,000 0.3 73 990.36 O B MPS-12 50 -500-2923 1-39 -00 PRO D 525 140 9/4/2009 720 SBHP 4,060 1,Q30 4 ,0 00 0 .383 1,00 7 OA+OB MPS-19A 50 -500 -29 23 1-21-0 1 PRO D 525 140 3/23/2009 7 ,532.28 SB HP 8 1 4,087.94 2,4 55 4,00 0 0.42 1 2,4 18.0 1 OA MPS-23 50-500-29230 -98 -00 PRO D 525 140 6/22/2009 1608 p p 4,0 10.22 1,200 4,000 0.39 1 1,196 OA+O B MPS-23 50 -500-29230 -98 -00 PROD 525 140 9/3/2009 792 pp 4,0 10.22 1,212 4,000 0.39 1 1,208 Gaining -10 psi/day in the OA +OB MPS-27 50-500-29230 -84-00 PRO D 525 140 4/8/2009 192 SB HP 3,932.17 1,102 4,0 00 0 .442 1,132 OA +OB MPS-27 50 -50 0-29 230-84-00 PRO D 525 140 712512009 408 pp 3,93 1.87 917 4,000 0.440 947 OA+O B MPS-28 50-500 -2923 1-58-00 PRO D 525 140 41612009 168 pp 3,8 20 .08 1,405 4,000 0 .44 5 1,485 NB MPS-34 50-500 -29231-7 1-00 PRO D 525 140 1/21/2009 1,368 pp 3,996.12 1,172 4,000 0.515 1,17 4 NE +OA MPS-34 50-500 -29231 -71 -00 PRO D 525 140 7/26/2009 288 pp 3,996.12 1,030 4,000 0.515 1,032 NE+OA MPS-35 50 -500 -2923 1-75-00 PROD 525 140 1/2 1/2009 504 pp 3,829 1,133 4,000 0.444 1,209 NB Avera~e 1,522 21. All tests reported he rein we re made in accorda nce with the applicable rules , regulations and instructions of the Alaska Oi l and Gas ConlNJation Commission. I hereby cert ify that the fo regoing is true and correct to the best of my know ledge. Signature Titl e Printed Name Date FL Flu id Leve l PBU Press ure Bu ild Up PFO Press ure Fa ll Off pp Pum p Press ure SB HP 1t-ln Botto m Hole Press ure Exhibit 3-G Sw Name MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-02 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPB-27 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-12 MPE-13B MPE-13B MPE-13B MPE-13B MPE-13B MPE-13B MPE-13B MPE-13B MPE-13B MPE-13B Month 1/1 /2009 2/1/2009 3/1/2009 4/1/2009 5/1/2009 6/1/2009 7/1/2009 8/1/2009 9/1/2009 10/1/2009 11/1/2009 12/1/2009 1/1/2009 2/1/2009 3/1/2009 4/1/2009 5/1/2009 6/1/2009 7/1/2009 8/1/2009 9/1/2009 10/1/2009 11 /1/2009 12 /1/2009 1/1/2009 2/1/2009 3/1/2009 4/1/2009 5/1 /2009 6/1/2009 7/1/2009 8/1/2009 9/1/2009 10 /1/2009 11 /1 /2 009 12/1/2009 1/1/2009 2/1/2009 3/1/2009 4/1/2009 5/1/2009 6/1/2009 7/1/2009 8/1/2009 9/1 /2009 10/1/2009 Injection Rate and Pressure Data Wellhead Pres Avg (psi) 1023.40 1017 .60 1024.40 968.80 1011 .70 1039.70 1139.30 1120.40 1043.60 1117.90 1059.50 982.90 1111.40 1131 .50 1166.50 1169.90 1144.6 0 1110.20 1124.70 1159.70 1180.30 1165.20 1175.40 1196.20 1160 .80 1182 .8 0 1176 .70 1252.60 1174.3 0 1154 .50 1082.60 1054.50 1086.40 891 .60 862.20 902 .6 0 1095 .70 1143 .70 1055.10 1060.30 1046.20 1047.50 988.00 1007.10 991 .20 980 .3 0 Days Operating 31 28 31 30 31 30 31 31 30 31 30 31 31 28 31 30 31 30 31 31 30 31 30 31 31 28 31 30 31 30 31 25 17 31 24 27 31 28 31 30 31 30 31 31 30 31 Product Code H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 Milne Point Field Schrader Bluff Pool lnj Vol Alloc (BBL, MCF) 11472 8428 11745 9512 10551 9245 12296 14511 10495 14805 11363 10390 20971 20981 23185 23833 19733 14831 17284 27433 19915 23779 24331 21771 31273 30564 36241 36593 35277 35281 35173 27060 19417 14451 10251 15107 10171 15681 24005 25590 24320 26015 20867 28005 20299 25687 Injection Rate (BBL, MCF) 370 301 379 317 340 308 397 468 350 478 379 335 676 749 748 794 637 494 558 885 664 767 811 702 1009 1092 1169 1220 1138 1176 1135 1082 1142 466 427 560 328 560 774 853 785 867 673 903 677 829 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPE-138 11 /1 /2009 1033.90 30 H20 26857 895 MPE-138 12/1/2009 1011.30 31 H20 26790 864 MPE-25A 1/1/2009 1320.10 31 H20 10828 349 MPE-25A 2/1/2009 1369.10 28 H20 13580 485 MPE-25A 3/1/2009 1371.50 3 1 H20 16755 540 MPE-25A 4/1/2009 1387 .00 30 H20 12921 431 MPE-25A 5/1/2009 1338.90 31 H20 8538 275 MPE-25A 6/1/2009 1298.00 30 H20 5433 181 MPE-25A 7/1/2009 1244 .80 31 H20 9070 293 MPE-25A 8/1/2009 1257.30 31 H20 9303 300 MPE-25A 9/1/2009 1270.70 30 H20 9406 314 MPE-25A 10/1 /2 009 1250.50 31 H20 11963 386 MPE-25A 11 /1/2009 1011 .30 3 H20 847 282 MPE-25A 12/1 /2009 0.00 0 H20 0 0 MPE-29 1/1/2009 812 .70 31 H20 13100 423 MPE-29 2/1/2009 840.50 28 H20 13671 488 MPE-29 3/1/2009 838 .60 31 H20 15539 501 MPE-29 4/1/2009 873 .10 30 H20 14810 494 MPE-29 5/1/2009 919 .90 31 H20 16633 537 MPE-29 6/1/2009 963.40 30 H20 17193 573 MPE-29 7/1/2009 990 .90 31 H20 25228 814 MPE-29 8/1/2009 1096 .00 31 H20 30837 995 MPE-29 9/1/2009 1023.20 30 H20 23958 799 MPE-29 10/1/2009 822.6 0 31 H20 14575 470 MPE-29 11/1 /2009 860 .10 30 H20 15303 510 MPE-29 12/1/2009 853 .10 31 H20 16387 529 MPG-01 1/1/2009 907 .90 31 H20 14336 462 MPG-01 2/1/2009 940 .30 28 H20 15755 563 MPG-01 3/1/2009 1107.40 31 H20 48486 1564 MPG-01 4/1/2009 1151 .60 30 H20 44583 1486 MPG-01 5/1/2009 1086 .60 30 H20 29788 993 MPG-01 6/1 /2 009 1001 .50 30 H20 17905 597 MPG-01 7/1/2009 1033 .00 20 H20 20699 1035 MPG-01 8/1/2009 1018 .70 31 H20 29905 965 MPG-01 9/1/2009 1031.60 30 H20 26667 889 MPG-01 10/1/2009 1052.50 31 H20 26768 863 MPG-01 11 /1 /2009 1088 .70 30 H20 31456 1049 MPG-01 12/1/2009 1054.40 31 H20 27273 880 MPG-03A 1/1/2009 1479 .00 31 H20 16969 547 MPG-03A 2/1/2009 1539 .60 28 H20 15223 544 MPG-03A 3/1/2009 1358 .30 31 H20 12042 388 MPG-03A 4/1/2009 1337 .80 30 H20 9965 332 MPG-0 3A 5/1/2009 1478.80 31 H20 15319 494 MPG-03A 6/1 /2009 1606.70 30 H20 16546 552 MPG-03A 7/1/2009 1413.30 20 H20 7707 385 MPG-03A 8/1/2009 1331 .00 31 H20 10019 323 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPG-03A 9/1/2009 1368.10 30 H20 8111 270 MPG-03A 10/1/2009 1368.40 31 H20 8836 285 MPG-03A 11/1/2009 1452.60 30 H20 11570 386 MPG-03A 12/1/2009 1436 .00 31 H20 7569 244 MPG-05 1/1/2009 0 .00 0 H20 0 0 MPG-05 2/1/2009 0 .00 0 H20 0 0 MPG-05 3/1/2009 0 .00 0 H20 0 0 MPG-05 4/1/2009 0.00 0 H20 0 0 MPG -05 5/1/2009 0 .00 0 H20 0 0 MPG-05 6/1/2009 0.00 0 H20 0 0 MPG-05 7/1/2009 0.00 0 H20 0 0 MPG-05 8/1/2009 0 .00 0 H20 0 0 MPG-05 9/1/2009 1000 .10 26 H20 17934 690 MPG-05 10 /1/2009 1157.80 31 H20 20293 655 MPG-05 11 /1 /2009 1193 .00 30 H20 18760 625 MPG-05 12/1/2009 1197.60 31 H20 19004 613 MPG-07 1/1/2009 2336.40 5 H20 1435 287 MPG-07 2/1/2009 1945.70 23 H20 7504 326 MPG-07 3/1/2009 1379 .50 16 H20 11429 714 MPG-07 4/1/2009 1368.50 30 H20 14430 481 MPG-07 5/1/2009 1393 .20 31 H20 15142 488 MPG-07 6/1/2009 1420.90 30 H20 13245 442 MPG-07 7/1/2009 1309.90 20 H20 5390 270 MPG-07 8/1/2009 1220.60 31 H20 8282 267 MPG-07 9/1/2009 1376.40 30 H20 17188 573 MPG-07 10/1/2009 1429 .10 31 H20 14191 458 MPG-07 11 /1/2009 1409 .70 28 H20 15858 566 MPG-07 12/1/2009 1266.30 31 H20 9810 316 MPG-09 1/1/2009 752 .00 27 H20 16177 599 MPG-09 2/1/2009 807 .80 24 H20 24820 1034 MPG-09 3/1/2009 1162.70 6 H20 2236 373 MPG-09 4/1/2009 829.90 30 H20 34654 1155 MPG-09 5/1/2009 902 .70 31 H20 39672 1280 MPG-09 6/1/2009 895.20 29 H20 32021 1104 MPG-09 7/1/2009 922.80 20 H20 22116 1106 MPG-09 8/1/2009 995 .00 31 H20 30928 998 MPG-09 9/1/2009 907 .10 30 H20 11944 398 MPG-09 10/1/2009 924.00 31 H20 11820 381 MPG-09 11 /1 /2009 893 .80 17 H20 7910 465 MPG-09 12 /1/2009 864 .90 31 H20 14792 477 MPG-10 1/1/2009 948.30 31 H20 31738 1024 MPG-10 2/1/2009 904 .90 28 H20 26605 950 MPG-10 3/1/2009 866.20 31 H20 25418 820 MPG-10 4/1/2009 866.30 30 H20 26033 868 MPG-10 5/1/2009 854 .70 31 H20 26513 855 MPG-10 6/1/2009 881 .00 30 H20 27888 930 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPG-10 7/1/2009 811.60 20 H20 14497 725 MPG-10 8/1/2009 865 .80 31 H20 31624 1020 MPG-10 9/1/2009 843 .10 30 H20 26554 885 MPG-10 10/1/2009 84 3 .70 31 H20 27092 874 MPG-10 11 /1/2009 859 .30 30 H20 26799 893 MPG-10 12/1/2009 819 .80 31 H20 26343 850 MPG-13 1/1 /2009 1269.70 31 H20 19763 638 MPG-13 2/1/2009 1278.30 28 H20 20964 749 MPG-13 3/1/2009 1298.60 31 H20 2478 3 799 MPG-1 3 4/1/2009 1270 .10 30 H20 18485 616 MPG-13 5/1 /2009 1280.40 30 H20 23141 771 MPG-13 6/1/2009 1291 .90 28 H20 25352 905 MPG -13 7/1/2009 1283.60 20 H20 16078 804 MPG-13 8/1 /2009 1267.30 31 H20 21974 709 MPG-13 9/1/2009 1265.40 30 H20 21364 712 MPG-13 10/1/2009 1274.80 31 H20 22170 715 MPG-1 3 11 /1 /2009 1271.30 30 H20 216 35 721 MPG-13 12/1 /2009 1232.40 31 H20 23467 757 MPG-17 1/1 /2009 134 5 .10 31 H20 21792 703 MPG-17 2/1/2009 1427.60 28 H20 21714 776 MPG -17 3/1 /2009 1352.50 31 H20 21688 700 MPG-17 4/1/2009 1369.40 30 H20 28974 966 MPG -17 5/1/2009 1305.30 31 H20 31125 1004 MPG-17 6/1/2009 636 .50 30 H20 21554 718 MPG-17 7/1/2009 1318.00 19 H20 12748 671 MPG-17 8/1 /2009 1371.50 3 1 H20 26639 859 MPG-17 9/1/2009 1325.00 30 H20 21578 719 MPG -17 10/1/2009 1313.70 31 H20 24557 792 MPG-17 11 /1 /2009 1332 .30 30 H20 26301 877 MPG-17 12/1/2009 1289.60 31 H20 26 325 849 MPG-19 1/1/2009 1296.20 29 H20 24175 83 4 MPG-19 2/1/2009 945.80 12 H20 121 37 1011 MPG-19 3/1/2009 790.40 29 H20 27850 960 MPG-19 4/1 /2009 839.10 30 H20 29961 999 MPG-19 5/1 /2009 851 .70 3 1 H20 3 1524 1017 MPG-19 6/1 /2009 887 .20 30 H20 30060 1002 MPG -19 7/1/2009 856 .70 20 H20 1831 8 916 MPG-19 8/1 /2009 997 .60 31 H20 35212 11 36 MPG-19 9/1/2009 1086.10 30 H20 32518 1084 MPG-19 10/1/2009 962.40 31 H20 28505 920 MPG-19 11 /1 /2009 976 .10 30 H20 30157 1005 MPG-19 12/1/2009 906 .90 31 H20 27915 900 MPH-11 1 /1 /2009 610.50 31 H20 16059 518 MPH-11 2/1/2009 656.20 28 H20 2407 3 860 MPH-11 3/1 /2009 668 .60 28 H20 24018 858 MPH-11 4/1 /2009 0 .00 0 H20 0 0 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPH-11 5/1/2009 0 .00 0 H20 0 0 MPH-11 6/1 /2009 0 .00 0 H20 0 0 MPH-11 7/1/2009 0.00 0 H20 0 0 MPH-11 8/1/2009 792.30 21 H20 19130 911 MPH-11 9/1/2009 1118.80 30 H20 16991 566 MPH-11 10/1/2009 1551 .30 31 H20 21189 684 MPH-11 11/1 /2009 1498.70 30 H20 16186 540 MPH-11 12/1/2009 1432.10 31 H20 13766 444 MPH-12 1/1/2009 1038.50 31 H20 6508 210 MPH-12 2/1 /2009 1054.60 28 H20 7110 254 MPH-12 3/1/2009 1035.10 31 H20 7123 230 MPH-12 4/1/2009 1078.70 30 H20 7832 261 MPH-12 5/1/2009 1062.30 31 H20 8283 267 MPH-12 6/1/2009 1020.20 30 H20 5152 172 MPH-12 7/1/2009 994.70 20 H20 3669 183 MPH-12 8/1/2009 994.40 31 H20 6289 203 MPH-12 9/1/2009 969 .30 30 H20 6364 212 MPH-12 10/1/2009 1089 .30 31 H20 11515 371 MPH-12 11 /1/2009 935.60 20 H20 3479 174 MPH-12 12/1/2009 924.70 31 H20 5178 167 MPH-15 1 /1 /2009 1179.10 31 H20 14946 482 MPH-15 2/1/2009 1442 .20 28 H20 14684 524 MPH-15 3/1/2009 1275.20 31 H20 11984 387 MPH-15 4 /1/2009 1330 .20 30 H20 12162 405 MPH-15 5/1/2009 1406.00 31 H20 18055 582 MPH-15 6/1/2009 1414.70 30 H20 17207 574 MPH -15 7/1/2009 1167.40 20 H20 6119 306 MPH-15 8/1/2009 1109.00 31 H20 9142 295 MPH -15 9/1/2009 1069.60 30 H20 8461 282 MPH-15 10/1/2009 1155.70 31 H20 14 119 455 MPH -15 11 /1 /2009 1164.80 30 H20 14208 474 MPH-15 12/1/2009 1014.90 3 1 H20 8232 266 MPH-17 1 /1 /2009 1403.70 3 1 H20 15114 48 8 MPH-17 2/1/2009 1530.10 28 H20 19345 691 MPH-17 3/1/2009 1417 .10 31 H20 15608 50 3 MPH-17 4 /1/2009 1256.60 30 H20 26304 877 MPH-17 5/1/2009 1197 .30 31 H20 23562 760 MPH-17 6/1/2009 1214.00 30 H20 24947 832 MPH -17 7/1 /2009 11 18.40 20 H20 14863 743 MPH-17 8/1 /2009 1108.00 31 H20 27420 885 MPH-17 9/1/2009 1102 .90 30 H20 25368 846 MPH-17 10/1/2009 1093.00 31 H20 28104 907 MPH -17 11 /1 /2009 1064.70 30 H20 26750 892 MPH-17 12/1/2009 1076.50 31 H20 24285 783 MPl-02 1/1/2009 1099.10 31 H20 20539 66 3 MPl-02 2/1/2009 1119.40 28 H20 21771 778 Exhibit 3-G Sw Name MPl-02 MPl-02 MPl-02 MPl-02 MPl-02 MPl-02 MPl-02 MPl-02 MPl-02 MPl-02 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-05 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-08 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 MPl-09 Month 3/1/2009 4/1/2009 5/1/2009 6/1/2009 7/1/2009 8/1/2009 9/1/2009 10/1/2009 11/1/2009 12/1/2009 1/1/2009 2/1/2009 3/1/2009 4/1/2009 5/1/2009 6/1/2009 7/1/2009 8/1/2009 9/1/2009 10/1/2009 11 /1 /2009 12/1/2009 1/1/2009 2/1/2009 3/1/2009 4/1/2009 5/1/2009 6/1/2009 7/1/2009 8/1/2009 9/1/2009 10/1/2009 11 /1 /2009 12/1/2009 1/1/2009 2/1 /2009 3/1 /2009 4/1 /2009 5/1 /2009 6/1 /2009 7/1/2009 8/1/2009 9/1 /2009 10/1/2009 11 /1 /2009 12/1/2009 Injection Rate and Pressure Data Wellhead Pres Avg (psi) 1147.40 1143.40 1118.30 1173.10 1087.60 1093.60 1038.10 1068 .00 1074.30 1030.70 845.30 855 .20 837.30 844.20 857.90 867.30 842.40 820.00 826.40 859.20 878.10 827.50 1167.50 1028.10 1092.20 1194.10 1192 .80 1153.70 1082.60 1086.90 1082 .10 1081 .50 1089.40 1060 .00 1352 .20 1358 .70 1366.40 1394.80 1032.50 1138.40 1145.90 1159.90 1124.90 1130.10 1137.80 1131 .60 Days Operating 31 28 31 30 22 31 30 31 30 31 31 28 30 30 31 30 20 31 30 31 30 31 31 28 31 30 31 27 21 31 30 31 30 31 31 28 31 14 19 30 22 31 30 31 30 31 Product Code H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 H20 Milne Point Field Schrader Bluff Pool lnj Vol Alloc (BBL, MCF) 25198 18499 22203 21918 14267 26002 20669 23564 25721 26729 24700 24294 21205 16664 16971 16573 12442 16305 16131 19859 23960 15248 47119 33375 42000 41722 39957 35322 25458 42187 43496 44702 44363 44047 42711 37742 43639 16693 30843 46523 30386 47545 39990 41477 44395 50989 Injection Rate (BBL, MCF) 813 661 716 731 649 839 689 760 857 862 797 868 707 555 547 552 622 526 538 641 799 492 1520 1192 1355 1391 1289 1308 1212 1361 1450 1442 1479 1421 1378 1348 1408 1192 1623 1551 1381 1534 1333 1338 1480 1645 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPl-10 1/1/2009 725 .4 0 31 H20 36360 1173 MPl-10 2/1/2009 722 .60 28 H20 32845 1173 MPl -10 3/1/2009 735 .80 31 H20 38369 1238 MPl-10 4 /1/2009 780 .90 30 H20 43887 1463 MPl-10 5/1/2009 791 .90 31 H20 44478 1435 MPl-10 6/1/2009 708.40 29 H20 33387 1151 MPl -10 7/1/2009 644 .90 21 H20 21110 1005 MPl-10 8/1/2009 628 .90 31 H20 31012 1000 MPl-10 9/1/2009 664 .60 30 H20 30937 1031 MPl-10 10 /1/2009 692 .90 31 H20 31773 1025 MP l-10 11 /1 /2009 655 .00 30 H20 23573 786 MPl-10 12 /1/2009 6 35 .60 31 H20 21462 692 MPl-16 1/1/2009 1255.60 31 H20 44306 1429 MPl -16 2/1/2009 1158 .20 28 H20 38515 1376 MPl-16 3/1/2009 1145.30 31 H20 42403 1368 MPl-16 4 /1/2009 1123.80 30 H20 39846 1328 MPl-16 5/1/2009 1147.10 23 H20 30637 1332 MPl-16 6/1/2009 1405.70 30 H20 40430 1348 MPl-16 7/1 /2009 1174.50 22 H20 27126 1233 MPl-16 8/1/2009 1147.40 31 H20 40669 1312 MPl-16 9/1/2009 1199 .90 30 H20 41556 1385 MPl-16 10 /1/2009 1189.00 31 H20 42893 1384 MPl-16 11 /1 /2009 1191.20 30 H20 41647 1388 MPl-16 12 /1/2009 1085 .70 31 H20 40866 1318 MPJ-02 1/1/2009 877 .50 31 H20 14869 480 MPJ -02 2/1 /2009 883.70 28 H20 17850 638 MPJ-02 3/1/2009 850.70 31 H20 18428 594 MPJ-02 4 /1/2009 799.00 30 H20 13663 455 MPJ-02 5/1/2009 846.10 31 H20 19036 614 MPJ-02 6/1/2009 861.60 30 H20 18901 630 MPJ-02 7/1/2009 813.00 17 H20 7104 418 MPJ-02 8/1/2009 0 .00 0 H20 0 0 MPJ-02 9/1/2009 0 .00 0 H20 0 0 MPJ-02 10/1/2009 0 .00 0 H20 0 0 MPJ-02 11 /1 /2009 0 .00 0 H20 0 0 MPJ-02 12/1/2009 0 .00 0 H20 0 0 MPJ-15 1 /1/2009 940 .20 31 H20 32193 10 38 MPJ-15 2/1/2009 952 .70 28 H20 32623 1165 MPJ-15 3/1/2009 953.90 31 H20 36567 1180 MPJ-15 4/1/2009 929.60 30 H20 30911 1030 MPJ-15 5/1/2009 933 .20 31 H20 33235 1072 MPJ-15 6/1/2009 9 36 .80 30 H20 27865 929 MPJ-15 7/1/2009 910 .70 21 H20 22946 1093 MPJ-15 8/1/2009 923 .30 31 H20 35642 1150 MPJ-15 9/1/2009 961 .50 30 H20 35668 1189 MPJ-15 10/1/2009 1009.50 3 1 H20 40767 1315 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPJ-15 11 /1 /2009 966.40 30 H20 34182 1139 MPJ-15 12/1/2009 837.40 28 H20 20807 743 MPJ-17 1/1/2009 891.40 31 H20 50812 1639 MPJ-17 2/1/2009 925.20 28 H20 48253 1723 MPJ-17 3/1/2009 931 .90 31 H20 50076 1615 MPJ-17 4/1/2009 957 .10 29 H20 46204 1593 MPJ-17 5/1/2009 979.70 31 H20 47896 1545 MPJ-17 6/1/2009 1023.30 30 H20 46653 1555 MPJ-17 7/1/2009 1018.40 20 H20 28337 1417 MPJ-17 8/1/2009 1009.50 31 H20 46802 1510 MPJ-17 9/1/2009 1089.70 22 H20 31120 1415 MPJ-17 10/1/2009 0 .00 0 H20 0 0 MPJ-17 11/1 /2009 1063 .70 16 H20 16625 1039 MPJ-17 12/1/2009 1051.80 31 H20 32451 1047 MPJ-18 1/1/2009 1272 .70 31 H20 18983 612 MPJ-18 2/1/2009 1264 .70 28 H20 18532 662 MPJ-18 3/1/2009 1264.50 31 H20 25082 809 MPJ-18 4/1/2009 1335 .10 30 H20 21321 711 MPJ-18 5/1/2009 1291 .10 31 H20 18957 612 MPJ-18 6/1/2009 1469.60 30 H20 20913 697 MPJ-18 7/1/2009 1346.00 20 H20 13243 662 MPJ-18 8/1/2009 1322 .60 28 H20 19758 706 MPJ-18 9/1/2009 1116.10 30 H20 12667 422 MPJ-18 10/1/2009 1446.70 31 H20 24873 802 MPJ-18 11/1/2009 1334.90 30 H20 19776 659 MPJ-18 12/1/2009 1158.10 31 H20 16148 521 MPJ -20A 1/1/2009 0.00 0 H20 0 0 MPJ-20A 2/1/2009 0 .00 0 H20 0 0 MPJ-20A 3/1/2009 0.00 0 H20 0 0 MPJ-20A 4/1/2009 0.00 0 H20 0 0 MPJ-20A 5/1/2009 0 .00 0 H20 0 0 MPJ-20A 6/1/2009 0 .00 0 H20 0 0 MPJ-20A 7/1/2009 0 .00 0 H20 0 0 MPJ-20A 8/1/2009 0 .00 0 H20 0 0 MPJ-20A 9/1/2009 0.00 0 H20 0 0 MPJ-20A 10/1/2009 0.00 0 H20 0 0 MPJ-20A 11/1/2009 0.00 0 H20 0 0 MPJ-20A 12/1/2009 0.00 0 H20 0 0 MPS-02 1/1/2009 811 .80 31 H20 44647 1440 MPS-02 2/1/2009 797 .00 28 H20 44267 1581 MPS -02 3/1/2009 789.20 9 H20 13304 1478 MPS -02 4/1/2009 0 .00 0 H20 0 0 MPS-02 5/1/2009 775.60 19 H20 15691 826 MPS-02 6/1/2009 1092.50 29 H20 25120 866 MPS-02 7/1/2009 1078.00 26 H20 19112 735 MPS-02 8/1/2009 659 .70 3 H20 1647 549 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPS-02 9/1/2009 584.80 27 H20 15792 585 MPS-02 10/1/2009 831 .00 31 H20 21961 708 MPS-02 11 /1 /2009 1085.60 30 H20 31073 10 36 MPS-02 12/1/2009 995 .70 31 H20 31903 1029 MPS-06 1/1/2009 1191.50 3 1 H20 19471 628 MPS-06 2/1 /2009 1233.30 28 H20 25166 899 MPS-06 3/1/2009 1235.90 31 H20 28489 919 MPS-06 4/1 /2009 1270.40 30 H20 25223 841 MPS-06 5/1/2009 1317.20 31 H20 25483 822 MPS-06 6/1/2009 1361.10 30 H20 26613 887 MPS-06 7/1 /2009 1410.90 31 H20 28399 916 MPS-06 8/1/2009 1327.00 31 H20 31882 1028 MPS-06 9/1/2009 1236.00 30 H20 15352 512 MPS-06 10/1/2009 1207.70 31 H20 19694 635 MPS-06 11 /1 /2009 1257.60 30 H20 18052 602 MPS-06 12/1/2009 1236.50 31 H20 16131 520 MPS-07 1/1/2009 1396.70 31 H20 32272 1041 MPS-07 2/1 /2009 1339.10 28 H20 33952 1213 MPS-07 3/1 /2009 1403.3 0 31 H20 45925 1481 MPS-07 4/1 /2009 1439.30 30 H20 43182 1439 MPS-07 5/1/2009 1436.10 31 H20 46592 1503 MPS -07 6/1/2009 1292.00 30 H20 37379 1246 MPS-07 7/1/2009 1313.20 31 H20 42194 1361 MPS-07 8/1/2009 1326.70 31 H20 45466 1467 MPS-07 9/1 /2009 1381.40 30 H20 48202 1607 MPS-07 10/1/2009 1387.60 31 H20 50665 1634 MPS-07 11 /1 /2009 1224.80 30 H20 35733 1191 MPS-07 12/1/2009 1114.30 31 H20 30929 998 MPS-09 1/1/2009 1212 .50 31 H20 16617 536 MPS-09 2/1/2009 1209.10 28 H20 17880 639 MPS-09 3/1/2009 1208.50 31 H20 20539 663 MPS-09 4/1/2009 1323.80 30 H20 21600 720 MPS-09 5/1/2009 1375.50 31 H20 21151 682 MPS-09 6/1/2009 13 30.40 30 H20 20355 679 MPS-09 7/1/2009 1281 .50 3 1 H20 20610 665 MPS-09 8/1/2009 1376.40 4 H20 2570 643 MPS-09 9/1/2009 1192.20 5 H20 3645 729 MPS -09 10 /1/2009 1221 .90 16 H20 9339 584 MPS -09 11 /1/2009 152.30 15 H20 8822 588 MPS-09 12/1/2009 0 .00 0 H20 0 0 MPS-10A 1/1/2009 12 .70 2 H20 855 428 MPS-10A 2/1/2009 116.10 28 H20 28037 1001 MPS-10A 3/1/2009 416 .90 31 H20 38068 1228 MPS-10A 4/1/2009 622 .50 29 H20 44547 1536 MPS-10A 5/1/2009 0.00 0 H20 0 0 MPS-10A 6/1/2009 0 .90 6 H20 4436 739 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPS-10A 7/1/2009 620 .80 20 H20 16160 808 MPS-10A 8/1/2009 782.50 15 H20 10503 700 MPS-10A 9/1/2009 2336 .00 2 H20 1129 565 MPS-10A 10/1/2009 13 .70 25 H20 13169 527 MPS-10A 11 /1/2009 15.20 22 H20 11728 533 MPS-10A 12/1/2009 3.80 1 H20 55 55 MPS-11 1/1/2009 655 .00 27 H20 37603 1393 MPS-11 2/1/2009 1182.10 28 H20 43449 1552 MPS-11 3/1/2009 1263.80 31 H20 47972 1547 MPS-11 4/1/2009 1149.30 30 H20 46469 1549 MPS-11 5/1/2009 330 .10 31 H20 23806 768 MPS-11 6/1/2009 1242.90 30 H20 38369 1279 MPS-11 7/1 /2009 658.10 9 H20 12127 1347 MPS -11 8/1/2009 951.00 27 H20 7157 265 MPS-11 9/1/2009 781.70 21 H20 15382 732 MPS-11 10/1/2009 781.90 25 H20 25406 1016 MPS-11 11/1/2009 32.90 16 H20 9470 592 MPS-11 12/1/2009 26.30 4 H20 3017 754 MPS -13 1/1 /2 009 0 .00 0 H20 0 0 MPS-13 2/1/2009 0.00 0 H20 0 0 MPS-13 3/1 /2009 0 .00 0 H20 0 0 MPS-13 4/1 /2009 0 .00 0 H20 0 0 MPS-13 5/1 /2009 0.00 0 H20 0 0 MPS -13 6/1/2009 0 .00 0 H20 0 0 MPS-13 7/1/2009 0 .00 0 H20 0 0 MPS-13 8/1 /2009 0 .00 0 H20 0 0 MPS-1 3 9/1 /2009 0 .00 0 H20 0 0 MPS-13 10/1/2009 0.00 0 H20 0 0 MPS-13 11/1 /2009 0.00 0 H20 0 0 MPS-13 12/1/2009 0.00 0 H20 0 0 MPS-14 1 /1 /2009 1067.40 31 H20 18584 599 MPS-14 2/1/2009 1080.70 28 H20 24071 860 MPS-14 3/1 /2009 1095.40 31 H20 32097 1035 MPS-14 4/1/2009 1147 .10 30 H20 33682 1123 MPS-14 5/1 /2009 1166.00 31 H20 32679 1054 MPS-14 6/1 /2009 1124 .00 30 H20 32291 1076 MPS-14 7/1 /2009 1119.00 31 H20 35801 1155 MPS-14 8/1/2009 1118.00 31 H20 35713 1152 MPS-14 9/1/2009 1125.70 30 H20 33356 1112 MPS-14 10/1/2009 1152.20 3 1 H20 35425 1143 MPS-14 11 /1 /2009 1142.90 30 H20 36244 1208 MPS-14 12/1/2009 1125.10 31 H20 32196 1039 MPS-15 1 /1 /2009 0 .00 0 H20 0 0 MPS-15 2/1 /2009 0.00 0 H20 0 0 MPS-15 3/1 /2009 0 .00 0 H20 0 0 MPS-15 4/1/2009 0 .00 0 H20 0 0 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPS-15 5/1/2009 0.00 0 H20 0 0 MPS-15 6/1/2009 0.00 0 H20 0 0 MPS-15 7/1/2009 0 .00 0 H20 0 0 MPS-15 8/1/2009 0 .00 0 H20 0 0 MPS-15 9/1/2009 0.00 0 H20 0 0 MPS-15 10/1/2009 0 .00 0 H20 0 0 MPS-15 11/1/2009 0.00 0 H20 0 0 MPS-15 12/1/2009 0 .00 0 H20 0 0 MPS-16 1/1/2009 1092.00 31 H20 49168 1586 MPS-16 2/1/2009 1154.70 28 H20 56771 2028 MPS-16 3/1 /2009 1164.20 31 H20 63912 2062 MPS-16 4/1/2009 1220.30 30 H20 60682 2023 MPS-16 5/1/2009 1189 .00 31 H20 55579 1793 MPS-16 6/1/2009 1222.00 30 H20 58334 1944 MPS-16 7/1 /2009 1177.80 31 H20 57585 1858 MPS-16 8/1/2009 1182.70 31 H20 66543 2147 MPS-16 9/1/2009 982 .10 30 H20 45777 1526 MPS-16 10/1/2009 1039.60 31 H20 50165 1618 MPS-16 11/1/2009 1001.90 30 H20 48174 1606 MPS-16 12/1/2009 973.00 31 H20 49556 1599 MPS-18 1 /1 /2009 953.30 31 H20 47751 1540 MPS-18 2/1/2009 1030.10 28 H20 55203 1972 MPS-18 3/1/2009 1147 .80 31 H20 70822 2285 MPS-18 4/1/2009 1185 .20 30 H20 63891 2130 MPS-18 5/1/2009 1007.80 31 H20 51428 1659 MPS-18 6/1/2009 830.30 30 H20 51671 1722 MPS-18 7/1/2009 820.40 31 H20 54747 1766 MPS-18 8/1/2009 845.80 31 H20 57585 1858 MPS-18 9/1/2009 726 .80 30 H20 37311 1244 MPS-18 10/1/2009 679.10 31 H20 40641 1311 MPS-18 11/1 /2009 621.20 17 H20 10406 612 MPS-18 12/1/2009 652.20 31 H20 34892 1126 MPS-20 1 /1 /2009 1029.40 31 H20 59255 1911 MPS-20 2/1/2009 1117.00 28 H20 69479 2481 MPS-20 3/1/2009 1115 .70 31 H20 77657 2505 MPS-20 4/1 /2009 1155.80 30 H20 75554 2518 MPS-20 5/1/2009 1185 .10 31 H20 76079 2454 MPS-20 6/1/2009 1165.80 30 H20 58132 1938 MPS-20 7/1/2009 1150.80 31 H20 66964 2160 MPS-20 8/1 /2009 1171 .20 31 H20 75796 2445 MPS-20 9/1/2009 1159.30 30 H20 55167 1839 MPS-20 10/1/2009 1146.50 31 H20 39706 1281 MPS-20 11 /1 /2009 1127.20 30 H20 41610 1387 MPS-20 12/1/2009 1096.30 31 H20 38312 1236 MPS-21 1/1/2009 0.00 0 H20 0 0 MPS-21 2/1/2009 0.00 0 H20 0 0 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Allee Injection Rate Sw Name Month Avg (psi) Operating Code (BBL , MCF) (BBL, MCF) MPS-21 3/1/2009 0 .00 0 H20 0 0 MPS-21 4/1/2009 0 .00 0 H20 0 0 MPS -21 5/1/2009 0 .00 0 H20 0 0 MPS-21 6/1/2009 0 .00 0 H20 0 0 MPS-21 7/1/2009 0 .00 0 H20 0 0 MPS-21 8/1/2009 0 .00 0 H20 0 0 MPS-21 9/1 /2009 0.00 0 H20 0 0 MPS-21 10/1/2009 0 .00 0 H20 0 0 MPS -21 11 /1 /2009 0 .00 0 H20 0 0 MPS-21 12/1/2009 0 .00 0 H20 0 0 MPS-26 1/1/2009 1245.60 31 H20 58809 1897 MPS-26 2/1/2009 1325.40 28 H20 60879 2174 MPS-26 3/1/2009 1402.40 31 H20 72760 2347 MPS-26 4 /1/2009 1355.90 30 H20 50648 1688 MPS-26 5/1/2009 1386.70 3 1 H20 50804 1639 MPS -26 6/1/2009 1243.30 29 H20 42667 1471 MPS-26 7/1/2009 1216.90 31 H20 4 3381 1399 MPS-26 8/1/2009 1173.00 31 H20 27481 886 MPS-26 9/1/2009 1106.40 30 H20 44850 1495 MPS-26 10/1/2009 1049.60 31 H20 47180 1522 MPS-26 11 /1 /2009 1026.30 30 H20 48373 1612 MPS-26 12/1/2009 966.60 3 1 H20 49195 1587 MPS-30 1 /1 /2009 707 .60 3 1 H20 35245 1137 MPS-30 2/1/2009 712 .30 28 H20 38656 1381 MPS-30 3/1/2009 764 .00 31 H20 45857 1479 MPS -30 4/1/2009 742 .00 30 H20 39606 1320 MPS-30 5/1/2009 602 .90 31 H20 27163 876 MPS-30 6/1/2009 574 .10 30 H20 26728 891 MPS-30 7/1/2009 626 .60 31 H20 33222 1072 MPS-30 8/1/2009 712 .80 31 H20 40810 1316 MPS-30 9/1/2009 785 .00 30 H20 45504 15 17 MPS-30 10 /1/2009 814 .00 31 H20 38161 1231 MPS-30 11 /1 /2009 856.30 30 H20 44916 1497 MPS-30 12/1/2009 880.60 31 H20 49997 1613 MPS-31 1/1 /2009 907 .30 30 H20 2452 8 81 8 MPS-31 2/1/2009 877.30 28 H20 21508 768 MPS-31 3/1/2009 1089.30 31 H20 42779 1380 MPS-31 4/1/2009 1200.50 30 H20 39685 1323 MPS-31 5/1/2009 1166.20 31 H20 31403 1013 MPS -31 6/1/2009 1168.70 30 H20 30658 1022 MPS -31 7/1/2009 1109.10 31 H20 25163 812 MPS-31 8/1/2009 1149.80 31 H20 26552 857 MPS -31 9/1/2009 1173.10 30 H20 25137 838 MPS-31 10/1/2009 1173 .80 31 H20 26681 861 MPS-31 11 /1 /2009 1209.80 30 H20 27984 933 MPS-31 12/1/2009 1178.50 3 1 H20 25346 818 Exhibit 3-G Injection Rate and Pressure Data Milne Point Field Schrader Bluff Pool Wellhead Pres Days Product lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Code (BBL, MCF) (BBL, MCF) MPS-33A 1/1/2009 1243.50 31 H20 16854 544 MPS-33 A 2/1/2009 1139 .10 28 H20 13255 473 MPS-33A 3/1/2009 1209.70 31 H20 19954 644 MPS-33A 4/1/2009 1207.60 30 H20 18180 606 MPS-33A 5/1 /2 009 1013.10 31 H20 20827 672 MPS-33A 6/1/2009 879.70 30 H20 16982 566 MPS-33A 7/1/2009 940.60 31 H20 21029 678 MPS-33A 8/1/2009 906.20 31 H20 18828 607 MPS-33A 9/1/2009 895.90 30 H20 21686 723 MPS-33A 10/1/2009 797 .8 0 31 H20 19142 617 MPS-33A 11 /1 /2009 750.40 30 H20 17937 598 MPS-33A 12/1 /20 09 695.70 31 H20 20146 650 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Milne Point Unit Allocation Factor Report 1I1 /2009 -12/31 /2009 Date Oil Water Gas 1/1/2009 0 .81 1.68 0 .84 1/2/2009 0 .82 1.61 0.91 1/3/2009 0.80 1.44 1.01 1/4/2009 0 .93 1.53 0.97 1/5/2009 0.91 1.26 0.95 1/6/2009 0 .96 1.18 0.91 1/7/2009 0.89 1.32 0.95 1/8/2009 0 .87 1.36 0 .88 1/9/2009 0 .87 1.37 0 .80 1/10/2009 0 .87 1.39 0 .88 1 /11 /2009 0 .8 8 1.31 1.02 1/12/2009 0 .84 1.39 0 .92 1/13/2009 0 .8 5 1.38 0.92 1/14/2009 0 .85 1.3 9 0.91 1/15/2009 0 .83 1.41 0.89 1/16/2009 0 .84 1.41 0.90 1/17/2009 0 .83 1.40 0 .89 1/18/2009 0 .83 1.43 0.92 1/19/2009 0 .83 1.40 0.90 1/20/2009 0.84 1.43 0.92 1/21/2009 0.86 1.42 0.92 1/22/2009 0 .84 1.42 0.91 1/23/2009 0 .83 1.46 0 .91 1/24/2009 0.85 1.46 0.98 1/25/2009 0.83 1.46 0.91 1/26/2009 0 .82 1.41 0 .8 9 1/27/2009 0 .8 4 1.41 0.88 1/28/2009 0.84 1.49 1.01 1/29/2009 0 .85 1.47 0 .98 1/30/2009 0.82 1.39 0 .99 1/31/2009 0.85 1.40 1.01 2/1/2009 0.83 1.52 1.01 2/2/2009 0.83 1.54 0.90 2/3/2009 0.83 1.48 0.88 2/4/2009 0.83 1.50 0 .91 2/5/2009 0.83 1.51 0.92 2/6/2009 0.83 1.50 0.89 2/7/2009 0 .84 1.50 0.96 2/8/2009 0 .8 1 1.45 0.94 2/9/2009 0 .82 1.42 0 .92 2/10/2009 0 .79 1.52 0 .88 2/11/2009 0 .78 1.40 0.91 2/12/2009 0 .81 1.49 0 .91 2/13/2009 0 .8 2 1.47 0.91 2/14/2009 0 .79 1 .23 0 .92 2/15/2009 0 .81 1 .30 0 .92 2/16/2009 0.83 1.29 0 .93 2/17/2009 0.81 1.37 0 .92 2/18/2009 0 .79 1.46 0.91 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 2/19/2009 0.80 1.50 0.87 2/20/2009 0 .76 1.25 0.94 2/21 /2009 0 .80 1.23 1.01 2/22/2009 0 .81 1.23 0.99 2/23/2009 0 .81 1.22 0.98 212412009 0 .81 1.22 0.99 2/25/2009 0 .83 1.26 1.06 2/26/2009 0 .82 1.36 1.07 212712009 0.79 1.43 0.96 2/28/2009 0 .79 1.41 0.97 3/1/2009 0.79 1.41 0.97 3/2/2009 0 .79 1.42 0.94 3/3/2009 0 .78 1.43 0.94 3/4/2009 0 .80 1.45 0.96 3/5/2009 0 .79 1.49 0.93 3/6/2009 0 .79 1.50 0 .98 3/7/2009 0 .80 1 .51 0 .97 3/8/2009 0.71 1 .39 0 .89 3/9/2009 0.80 1.51 0 .94 3/10/2009 0.78 1 .50 0 .96 3/11/2009 0.80 1.47 0 .93 3/12/2009 0 .79 1.44 1 .02 3/13/2009 0.79 1.40 1 .02 3/14/2009 0.79 1.40 1 .01 3/15/2009 0.79 1.40 1.01 3/16/2009 0 .79 1.38 1.03 3/17/2009 0 .78 1.37 0 .99 3/18/2009 0.79 1.33 0.99 3/19/2009 0.80 1.36 0 .99 3/20/2009 0 .82 1.36 1.02 3/21/2009 0 .82 1.28 1.02 3/22/2009 0 .85 1.27 1.03 3/23/2009 0 .83 1 .31 1.07 3/24/2009 0 .86 1 .26 1.01 3/25/2009 0.86 1 .23 1.00 3/26/2009 0 .84 1.18 0.98 3/27/2009 0 .84 1.23 0.96 3/28/2009 0 .82 1.23 0.94 3/29/2009 0 .81 1.25 0.92 3/30/2009 0.80 1.26 0.91 3/31/2009 0.80 1.29 0.97 4/1/2009 0 .84 1.26 1 .01 41212009 0 .82 1.29 1 .03 4/3/2009 0 .81 1.30 1.04 4/4/2009 0.81 1.26 1.00 4/5/2009 0.81 1.20 0 .99 4/6/2009 0 .79 1 .26 0 .98 4/7/2009 0.80 1 .26 0 .99 4/8/2009 0 .83 1 .29 1.02 4/9/2009 0 .83 1.31 1 .01 4/10/2009 0 .79 1.43 1.06 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 4/11/2009 0.85 1.3 1 1.03 4/12/2009 0 .77 1.25 1.02 4/13/2009 0 .83 1.22 1.04 4/14/2009 0.81 1.20 1.06 4/15/2009 0 .79 1.20 1.04 4/16/2009 0 .80 1.22 1.01 4/17/2009 0.78 1.30 1.00 4/18/2009 0.77 1.28 0.99 4/19/2009 0.77 1.30 1.01 4/20/2009 0 .78 1.30 1.01 4/21/2009 0 .75 1.29 1.01 4/22/2009 0 .76 1.34 1.03 4/23/2009 0 .78 1.25 1 .03 4/24/2009 0.81 1.27 1 .03 4/25/2009 0.81 1 .31 1.04 4/26/2009 0.79 1.31 0.99 4/27/2009 0.82 1.26 0.91 4/28/2009 0.81 1.22 0.83 4/29/2009 0.81 1.19 0 .94 4/30/2009 0.83 1.18 1.00 5/1/2009 0.82 1.17 0 .99 5/2/2009 0.82 1.17 1.03 5/3/2009 0.80 1.19 1.00 5/4/2009 0 .8 2 1.16 1 .03 5/5/2009 0.81 1.16 1.03 5/6/2009 0.80 1.14 1.01 5/7/2009 0.80 1.22 1 .02 5/8/2009 0.81 1.24 1 .03 5/9/2009 0 .8 2 1.21 1 .01 5/10/2009 0.81 1.22 0 .98 5/11/2009 0 .8 0 1.18 1.00 5/12/2009 0 .81 1.17 0 .98 5/13/2009 0 .82 1.18 0 .96 5/14/2009 0 .8 0 1.22 0 .90 5/15/2009 0 .8 0 1.22 0 .94 5/16/2009 0 .82 1.22 0.96 5/17/2009 0 .79 1.20 0 .98 5/18/2009 0 .8 0 1.19 1.06 5/19/2009 0 .8 2 1.22 1.07 5/20 /2 009 0 .81 1.18 1.13 5/21 /2009 0.83 1 .22 1 .1 0 5/22/2009 0 .82 1 .20 1 .07 5/23/2009 0 .81 1.29 1.07 5/24/2009 0 .82 1 .29 1.07 5/25/2009 0 .82 1 .24 1 .04 5/26/2009 0 .8 2 1.24 1.03 5/27/2009 0 .82 1 .29 1 .05 5/28/2009 0 .8 1 1.30 1 .03 5/29/2009 0 .83 1.27 1 .05 5/30/2009 0.82 1.29 1 .07 5/31 /2 009 0.80 1.25 1.05 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 6/1/2009 0 .81 1.22 1.04 6/2/2009 0 .82 1.21 1.04 6/3/2009 0 .82 1 .20 1.06 6/4/2009 0.81 1.23 1.03 6/5/2009 0 .82 1 .20 1.02 6/6/2009 0 .81 1.21 1.03 6/7/2009 0.83 1.20 1.04 6/8/2009 0 .81 1 .22 1.04 6/9/2009 0.81 1.23 1.03 6/10/2009 0 .79 1 .27 1.04 6/11/2009 0 .79 1.27 1.01 6/12/2009 0 .79 1.27 1.05 6/13/2009 0 .78 1.24 1.03 6/14/2009 0.78 1.23 1.04 6/15/2009 0 .79 1.27 1.06 6/16/2009 0.79 1.27 1.06 6/17/2009 0 .78 1.31 1.06 6/18/2009 0 .78 1.28 1.04 6/19/2009 0 .80 1.30 1.02 6/20/2009 0 .83 1.33 1 .05 6/21/2009 0.99 1.40 1.04 6/22/2009 0 .80 1.31 1 .02 6/23/2009 0 .81 1.25 1 .07 6/24/2009 0 .80 1.24 0 .97 6/25/2009 0 .78 1.23 0 .84 6/26/2009 0.81 1.20 0 .83 6/27/2009 0 .78 1.24 0 .81 6/28/2009 0 .80 1.18 0.80 6/29/2009 0.81 1.19 0.80 6/30/2009 0 .79 1.20 0 .81 7/1/2009 0 .93 1.09 0 .86 7/2/2009 0 .91 1.14 0 .83 7/3/2009 0.92 1.18 0 .83 7/4/2009 0 .91 1.14 0 .84 7/5/2009 0.91 1.15 0.83 7/6/2009 0.89 1.17 1.11 7/7/2009 0.92 1.24 1.14 7/8/2009 0 .94 1 .21 1.18 7/9/2009 0 .93 1 .19 1.15 7/10/2009 0.95 1.22 1.53 7/11/2009 0.94 1.21 1.58 7/12/2009 0 .91 1.24 1.41 7/13/2009 0 .92 1.22 1.43 7/14/2009 0.92 1.28 1.41 7/15/2009 0 .79 1.82 1.41 7/16/2009 0 .86 1.69 1.06 7/17/2009 0 .82 1.66 0.89 7/18/2009 0.93 1.66 1 .37 7/19/2009 0.84 1.64 1 .00 7/20/2009 0 .94 1.65 1.04 7/21/2009 0.88 1.68 1.05 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 7/22/2009 0 .89 1.67 1.02 7/23/2009 0.93 1 .68 1 .24 7/24/2009 0 .95 1.63 1.07 7/25 /2009 0.93 1.47 0.93 7/26 /2009 0.93 1.32 0 .90 7/27 /2009 0 .95 1.24 1.24 7/28/2009 0 .91 1.14 1 .16 7/29 /2009 0 .94 1.37 1.15 7/30 /2009 0.95 1.47 0 .99 7/31/2009 0.95 1.48 0 .97 8/1/2009 0.95 1.50 0.89 8/2/2009 0.97 1.51 0 .89 8/3/2009 0.97 1.50 1.06 8/4/2009 0 .94 1.49 1.11 8/5/2009 0 .95 1.47 1.27 8/6/2009 0.95 1.50 1.02 8/7/2009 0 .96 1.61 1 .07 8/8/2009 0.99 1.65 1.13 8/9/2009 0.97 1.53 0.99 8/10/2009 0.98 1.54 1.17 8/11 /2009 1.00 1.36 1.36 8/12 /2009 0 .98 1.29 1 .16 8/13/2009 0 .94 1.28 1.13 8/14/2009 0 .95 1.25 1.04 8/15/2009 0 .96 1.25 1 .11 8/16/2009 0 .94 1.21 1.12 8/17/2009 0 .95 1.23 1.04 8/18/2009 0 .94 1.20 0.94 8/19/2009 0 .95 1.20 0.96 8/20/2009 0.95 1.14 0.99 8/21 /2 009 0 .95 1.11 0 .98 8/22 /2009 0.95 1.15 0 .93 8/23/2009 0 .95 1.18 1.06 8/24/2009 0 .94 1.13 1.05 8/25/2009 0 .95 1.18 1.11 8/26/2009 0.95 1.16 1.10 8/27/2009 0 .96 1.20 1.12 8/28/2009 0.94 1.19 1.05 8/29/2009 0.95 1 .18 1.02 8/30 /2009 0.95 1 .17 1.02 8/31 /2009 0 .95 1.18 1.04 9/1/2009 0 .96 1.17 1.07 9/2/2009 0.94 1.17 1.07 9/3/2009 0.95 1 .17 1.06 9/4/2009 0 .96 1.17 1.09 9/5/2009 0.97 1 .16 1.09 9/6/2009 0.98 1.12 1.09 9/7/2009 0 .97 1.13 1.10 9/8/2009 0 .97 1 .14 1.10 9/9/2009 0.97 1.13 1.14 9/10/2009 0 .97 1.21 1.21 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 9/11 /2009 0 .98 1 .17 1 .10 9/12/2009 0 .98 1.18 1 .09 9/13/2009 0 .95 1.16 1 .09 9/14/2009 0.97 1 .12 1 .06 9/15/2009 0.99 1.14 1.04 9/16/2009 0.98 1 .13 1 .01 9/17/2009 0.96 1 .11 1 .05 9/18/2009 0 .97 1 .14 1 .04 9/19/2009 0 .96 1 .15 1 .06 9/20/2009 0 .93 1 .17 1 .07 9/21/2009 0 .98 1 .15 1 .05 9/22/2009 0.95 1 .13 1 .05 9/23/2009 0 .95 1 .17 1 .05 9/24/2009 0.99 1.15 1 .05 9/25/2009 0.98 1 .12 1 .04 9/26/2009 0 .98 1.11 1 .09 9/27 /2009 0.96 1 .12 1 .08 9/28/2009 0 .95 1.11 1.16 9/29/2009 0 .95 1.14 1 .15 9/30/2009 0 .96 1 .14 1.16 10/1/2009 0 .96 1 .13 1 .16 10/2/2009 0.96 1.17 1 .16 10/3/2009 0 .95 1 .18 1 .12 10/4/2009 0 .96 1 .16 1 .15 10/5/2009 0.95 1.16 1 .15 10/6/2009 0 .98 1.18 1 .15 10/7/2009 1.00 1 .17 1 .15 10/8/2009 0 .99 1.15 1.13 10/9/2009 0 .98 1 .16 1 .16 10/10/2009 0 .96 1.22 1 .19 10/11 /2009 0 .98 1 .21 1 .18 10/12/2009 0 .97 1 .18 1.19 10/13/2009 0 .97 1.18 1 .16 10/14/2009 0 .97 1.16 1 .16 10/15/2009 0 .96 1.19 1 .22 10/16/2009 0 .95 1.16 1.30 10/17/2009 0.97 1.17 1 .34 10/18/2009 0.94 1.15 1 .31 10/19/2009 0 .97 1.13 1.10 10/20 /2009 0 .96 1.06 1.08 10/21 /2009 0.94 1.05 1.07 10/22/2009 0.86 1.38 1.80 10/23 /2009 1 .02 1 .15 1.08 10/24 /2009 0 .96 1.35 1.45 10/25 /2009 0.97 1 .22 1.28 10/26/2009 0 .96 1.14 1.2 1 10/27/2009 0 .95 1.05 1.12 10/28 /2009 0 .93 1 .23 1.18 10/29 /2009 0 .95 1 .20 1 .13 10/30 /2009 0 .92 1 .28 1 .18 10/31 /2009 0.94 1 .17 0 .52 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 11 /1 /2009 1.01 1.16 1.25 11 /2/2009 0 .96 1.16 1.25 11/3/2009 0 .97 1.16 1.24 11 /4/2009 0.96 1.17 1.24 11 /5/2009 0 .97 1.16 1.23 11 /6/2009 0.97 1.15 1 .19 11 /7/2009 0 .98 1.16 1 .17 11 /8/2009 0 .97 1.15 1.16 11 /9/2009 0 .96 1.14 1 .15 11 /10/2009 0 .96 1.14 1 .13 11 /11 /2009 0 .94 1.15 1.13 11/12/2009 0.95 0.81 1.16 11 /13/2009 0.96 0 .84 1.15 11/14/2009 0.95 0 .98 1.15 11 /15/2009 0 .97 0.82 1.14 11/16/2009 0 .95 0 .87 1.11 11 /17/2009 0 .99 1.06 1.04 11/18/2009 0.95 1 .10 1.11 11 /19/2009 1.04 1 .07 1 .15 11/20/2009 0.95 1.05 1.18 11 /21 /2009 0 .96 1.06 1.21 11/22/2009 0 .97 1.07 1.16 11/23/2009 0 .95 1.08 1.12 11/24/2009 0.98 1.08 1 .13 11 /25/2009 0 .96 1.10 1.17 11 /26/2009 0 .98 1.11 1.17 11 /27/2009 0 .96 1.10 1.16 11/28/2009 0 .97 1 .05 1.18 11/29/2009 0 .97 1 .07 1.21 11 /30/2009 0 .98 1.07 1.20 12/1 /2009 0 .99 1.13 1.16 12 /2/2009 0 .98 1.13 1.21 12 /3/2009 0 .98 1.12 1.23 12 /4/2009 0 .99 1.17 1.21 12 /5/2009 0 .97 1.17 1.17 12 /6/2009 0 .98 1.18 1.21 12/7/2009 0 .96 1.20 1.26 12/8/2009 0 .96 1.17 1.25 12/9/2009 0.95 1.19 1.26 12/10/2009 0.96 1.16 1.25 12/11 /2009 0 .95 1.17 1.25 12/12/2009 0 .98 1.18 1 .25 12/13/2009 0 .95 1 .1 9 1.20 12/14/2009 0 .95 1.21 1.22 12/15/2009 1 .00 1.17 1.20 12/16/2009 0.98 1.20 1.18 12/17/2009 0 .98 1.18 1 .19 12/18/2009 0.99 1 .16 1 .17 12/19/2009 0.98 1.22 1 .13 12/20 /2009 0 .98 1.19 1.21 12/21 /2009 0 .99 1.17 1.19 Exhibit 3-H 2009 Facility Allocation Factors Milne Point Unit Date Oil Water Gas 12/22/2009 0 .99 1.17 1.17 12/23/2009 0.99 1.19 1.00 12/24/2009 0.98 1.20 0 .96 12/25/2009 1.00 1.22 0.99 12/26/2009 1.01 1.25 0.94 12/27/2009 0.99 1.25 0.92 12/28/2009 0 .99 1 .11 0 .86 12/29/2009 0.96 0.89 0 .83 12/30/2009 0.96 0 .90 0.84 12/31/2009 0.94 0.98 0 .84 Mean 0 .89 1 .26 1.05 Standard 0.077 0 .152 0.134 Deviation Waterflood Pattern Map Section 4 Sag River Oil Pool List of Exhibits Total Reservoir Production Plot Total Reservoir Injection Plot Pertinent Data Summary Reservoir Voidage Balance Static Pressure Data Injection Rate & Pressure Data By Well 4-A 4-B 4-C 4-D 4-E 4-F 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 2009, there were two active Sag production wells (MPF-33A and MPC-23) and one active injection well (MPF-73A). Exhibit 4-B shows a production plot for the Sag River reservoir covering the entire history through December 2009. 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 412 STBD, gas production averaged 256 MSCFD, and water production averaged 253 STBD in 2009. Cumulative production through the end of 2008 is 2.04 MMSTB of oil, 2.03 BSCF of gas, and 1.86 MMSTB of water. In 2009, the average water cut was 37 .8% which is a significant decrease over the 2008 average water cut of 53.4%. In 2009, the average GOR was 617 SCF/STB which is a decrease from the 2008 average GOR of 691 SCF/STB. The decrease in water cut and decrease in GOR are largely due to MPC- 23 returning to production. Exhibit 4-C shows an injection plot for the Sag River reservoir through December 2009. The only injector (MPF-73A) started water injection in July 2002. The water injection rate for 2009 averaged 929 BWD, with no gas injected. Cumulative water injection since waterflood startup through the end of 2009 is 2.02 MMSTB and cumulative gas injection for the same period is 0.32 BSCF. Both MPF-33A and MPF-73A were online for the majority of 2009. MPC-23 was brought online in October 2009 and produced through the end of the year. 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 2009. Exhibit 4-G provides a monthly summary of the injection rate and injection pressure data for the Sag River Oil Pool injector. Monitoring for connectivity between MPF-73A and MPF-33A is ongoing . There are some indications that the wells are connected and monitoring efforts will continue through 2010 to confirm waterflood interaction. Exhibit 4·A River Formation Waterflood Ma Miine Point Fleld March 2009 + SGB Marker_polnt V\Atterflood Potygon_reglon 1,000 2,000 3,000 Feet --- - Exhibit 4-B BP ALASKA -Milne Point Unit SAG Reservoir, Total Production 10000 10000 ~> >< <t c 1000 I 'I• II A -U. em ~ ii: 0 Ill I- I-(/J (/J -"~ .I 1000 (/J :ii -Ill Ill I-I-(/J (/J :ii ~ ~ 100 -l-11-lJlf-!--l I 11 1 I l I-\ I l -.JLJ!f,--lli-HH ~-=---l-lR.._,-tlttJE.l'-f.11 11 \IMI"' I 1--1 c 0 0;:: --() 13 :I :I 'C 'ti 0 0 ... ... c... I ~ li; 10 +-U--1 I • I I Ill ~ l --+-1-11---11---l 0 'lii == t 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 -Oil Prod Cum SAG -oil Prod Rate SAG -water Prod Cum SAG -water Prod Rate SAG -Gas Prod Rate SAG -Gas Prod Cum SAG 100.0 90.0 I I I I I I I I I I I ~- QI 80.0 I 11 1 c I I II :i I I I c I I 70.0 - 100 10 4.5 4.0 3.5 0 ~(Ja I I Ill ' • + 3 .. 0 ... ' QI () 60.0 I .-----:I I I I 2 .. 5 8 'ti II • 1111. 0 ,::-I 0:. 50.0 ...... 'II: i T ~ --I 2.0 g ~ 40.0 --l 0 ... I I . ~ ~ I :I • : ¥ll ~, 0 I ,. ~ I I+ 1.5 ... 30.0 .V' ' : $ ~ ~·~ ~~ ~ ~J =~ l. I ~ , ~ Ill j . , I == 20.0 t 1 .0 ' . , I , ::tr t!IW ~· ' ~j I ' " 11 ~ I: ~ ~ 10 0 I 0 .5 . I.-I I •-I . . ' -~ ·~ ..... 0.0 ·- ~ 0 .0 95 96 97 98 99 00 01 02 03 04 05 06 07 08 09 [=+=-F>rociucersonune--wtr cut % --*""" Gas1oi1 Ratio sAG I 2009 production_injection.xls u: 0 (/J :ii ~ c 0 ~ :I 'C 0 0:. Ill Ill CJ 3/24/2010 :;;:-< 0 -. m I-en ai I-en ~ c 0 :;::; (,) Cl> :5 Q; -Ill :;: Exhibit 4-C BP ALASKA -Milne Point Unit SAG Reservoir, Injection 10000 10000 .~ 1000 1000 100 100 03 10+:~~---::-:-~~-+-~~--1~~~-i...~~~(._~~~~~~l-~~_J ~ 10 05 04 06 09 07 08 ):' < 0 Li: 0 en ~ u: 0 en ::E ::E c 0 n Cl> :5 I/I Ill " I-water lnj Cum SAG -water lnj Rate SAG -Gas lnj Cum SAG --*-Gas lnj Rate SAG ] 2 -r-~~~.,--~~~...-~~--..~~~-.-~~~-.-~~~--,--~~~...,.-~~---. ~ I 1111111,11111111111•1111111111• = ------<? -~ 1 I 1111111111 : : " I » 0 ti Cl> :5 '11: 0 +-~~--1~~~-t-~~~-i-~~~r--~~-r~~~-r-~~~-r-~~--1 02 03 04 05 06 07 08 09 !•water Injector Online • Gaslrl]6Ct0r-Online I 2009 production_injection.xls 3/24/2010 Exhibit 4-D Milne Point Unit -Sag River Oil Pool SUMMARY OF PERTINENT DATA WATERFLOOD START-UP DATE: PRODUCTION Prior to Waterflood Start-Up: Oil (MSTB) Gas (MMSCF) Water (MSTB) Since Waterflood Start-Up: Oil (MSTB) Gas (MMSCF) Water (MSTB) FLUID INJECTION Since Waterflood Startup: Injection Water (MSTB) Injection Gas (MMSCF) As of December 31, 2009 AVERAGE OF PRESSURES OBTAINED IN 2009@ 8,700' TVD ss December, 2009 Pressure (psig) WELL COUNT (Wells in Operation)* Production Wells WAG Injection Water Only Injection Gas Only In j ection Notes: * Reflects ONLY operating wells. July 1, 2002 1 ,299 1 ,302 1,481 740 726 374 2 ,022 324 3 ,969 2 0 0 Exhibit 4-E RESERVOIR VOIDAGE BALANCE January -December 2009 Production: Injection: Oil Water Gas Reservoir Water Gas Month Prod Rate Prod Rate Prod Rate Voidage lnj Rate lnj Rate (stb/day) (stb/day) (mscf/day) (rbbVday) (stb/day) (mscf/day) 1/31 /2009 90..5483871 26.64516129 33.51612903 154 1024.612903 2/28/2009 185 269.2142857 110.6071429 534 983.8214286 3/31/2009 187.8387097 368.3225806 1422258065 659 1039.903226 4/30/2009 183.3 266.5333333 136.8666667 547 1054.933333 5/31 /2009 193.0967742 230.3225806 135 518 1029.870968 6/30/2009 180.1 191.8 97.63333333 448 845.9666667 7/31 /2009 132.8387097 146..2903226 36.09677419 335 537.0322581 8/31 /2009 298.516129 312.0967742 128.7096774 736 849.9677419 9/30/2009 281.5333333 269.2 135.0333333 669 831.8 10/31 /2009 685.4193548 283.:2903226 519.8709677 1,322 910.6774194 11 /30/2009 1105.1 209.7 925.8666667 1,938 998.2 12/31/2009 1102.677419 240.3548387 450..9354839 1,789 1133.548387 Average : 2009 385 234 238 804 937 0 Cumulative : mstb mstb mmscf mrb mstb mmscf 31-Dec-09 2.039 1,855 2.0ZB 5,290 2.022 324 Page I Voidage Replacement (rbbVday) 0 1,045 0 1,003 0 1,061 0 1,076 0 1,050 0 863 0 548 0 867 0 848 0 929 0 1,018 0 1,156 955 mrb 2,281 Milne Point Unit Sag River Oil Pool Voidage Voidage Replacement Balance Ratio (rbbVday) 6 .79 891 1.88 470 --402 --529 2.03 532 1.93 415 0 .00 213 0 .00 131 1.27 180 0 .70 -393 0 .00 -920 0 .65 -633 1.19 151 mrb 0 .43 -3 ,008 Exhibit 4-F Sta ti c Press ure Data STATE OF A LASKA ALASKA OIL AND GAS CONSERV ATION COM M ISSION RESERVOIR PRESSURE REPORT 1. Ope rator: BPXA 2. Address: 900 E. Benson Blvd Anchorage, Alaska 99508 -4254 3. U nit or Lease Name: Milne Point 4. Field and Poo l: Sag River Oil Pool 5. Da tum Reference: 8750' SS 8. We ll Name 9. API Number 50-XXX-XXXXX-XX-XX 10. Oil (0) or Gas 11 . AOGCC 12. Final Test 13. Shut-In Time, 14. Press. 15. B.H. Temp. 16. Depth Tool 17. Final and Number: (G) Pool Code Date Hours Surv. Type TVDss Observed (see Pressure at instructions for Tool Depth MPC-23 50-500 -29226 -43-00 PROD 525 150 10/15/2009 66,096 pp 8,580.04 3,894 MP F-33A 50 -500 -29226-89 -01 PRO D 525100 1/25/2009 288 SBHP 2 15 8456 .85 1565.00 2 1. All tests reported herein were made in accordance w it h the applicable rules, regulations and instructions of the Alaska O il and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to th e best of my knowledge. Signature Pri nted Name FL PBU PFO pp S BHP Fluid Leve l Pressu re Bui ld Up Press ure Fall Off Pu mp Pressu re Shut-In Bottom Ho le Pressure Title Da te Sag River Oil Poo l 6. Oil Gravity: AP I -34 7. Gas Gravity: Air = .65 18. Datum TVDss (input) 19. Press ure 20. Pressu re at Grad ient, Datum (ca l) psi/ft. 8,750 0.44 1 3,969 8,750 0.385 1,678 Exhibit 4-G Injection Rate and Pressure Data Milne Point Field Sag River Pool Wellhead Pres Days lnj Vol Alloc Injection Rate Sw Name Month Avg (psi) Operating Product Code (BBL, MCF) (BBL, MCF) MPF-73A 1/1/2009 3157 31 H20 31,763 1025 MPF-73A 2/1/2009 3016 28 H20 27,547 984 MPF-73A 3/1/2009 2927 31 H20 32 ,237 1040 MPF-73A 4/1/2009 2921 30 H20 31 ,648 1055 MPF-73A 5/1/2009 2953 31 H20 31 ,926 1030 MPF-73A 6/1/2009 2755 25 H20 25,379 1015 MPF-73A 7/1/2009 2679 20 H20 16,648 832 MPF-73A 8/1/2009 2909 31 H20 26,349 850 MPF-73A 9/1/2009 2957 30 H20 24,954 832 MPF-73A 10/1/2009 2796 31 H20 28,231 911 MPF-73A 11/1 /2009 2860 30 H20 29,946 998 MPF-73A 12/1/2009 2962 31 H20 35,140 1134 Section 5 Production/Injection Well Surveillance List of Exhibits Milne Point Surveillance 1/1/2009 -12/31/2009 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 multiple sand injectors annually and on new multiple sand injectors. There were 24 existing Kuparuk multi-sand injectors in 2009. Eight injection surveys were obtained in 2009. All of the injection surveys were performed in multi-sand injectors. So, surveys were obtained in 8 of the 24 multi-sand injectors. There were 27 existing Schrader Bluff multi-sand injectors in 2009, three of which were shut in all year. So 24 operating Schrader Bluff multi-sand injectors existed in 2009, and nine injection surveys were run in 2009. No injection survey was needed in the Sag River Oil Pool because it is a single zone reservoir. 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. In 2009, four production logs were obtained in Kuparuk gas lift producers. No production logs were run in Schrader Bluff wells in 2009. 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 and will remain inactive until further analysis. Exhibit 5-A is a summary of the Milne Point field well surveillance performed in 2009 on both producers and injectors. Exhibit 5-A Project Well Type Rec Date Kuoaruk Prod 7/14/2009 Kuparuk Prod 3/13/2009 Kuparuk Prod 11 /17/2009 Kuparuk Prod 10/24/2009 Kuparuk lni 6/6/2009 Kuparuk lnj 6/26 /2009 Kuoaruk lni 6/27/2009 Schrader lni 6/28/2009 Schrader lni 4/1/2009 Schrader lni 6/14/2009 Schrader lni 6/3/2009 Schrader lni 6/15 /2009 Schrader lni 6/16/2009 Kuparuk lni 9/1/2009 Schrader lni 6/5/2009 Schrader lni 9/18/2009 Kuoaruk lnj 6/30 /2009 Kuparuk lni 9/17/2009 Kuparuk lni 6/29/2009 Schrader lni 7/16/2009 Kuparuk lni 9/1/2009 Kuparuk lni 9/1/2009 Dedi cated inje ction into sinole sand Full Suite Production Loo Geochemical Analysis of Produ ction splits Spinner, Temperature , Pressure Pulsed Decavl Milne Point Unit 2009 Surveillance Kuparuk River Oil Pool Schrader Bluff Oil Pool Log Type Comments PPROF Splits : 0 % C Sand , 100% B Sand PPROF Solits : 25% A3 Sand , 31 % C Sand , 25 % A2 Sand 19 % B Sand PPROF Splits: 100% C Sand PPROF Splits: 13 % B+C Sand , 87% A3 Sand IPROF Splits: 84% C+B Sand , 16% A Sand IPROF Splits: 16 % B Sand , 84% A 3+A2+A IPROF Splits: 62 % B Sand , 38% C Sand IPROF Splits: 100% OA Sa nd IPROF Splits: 45 % OA Sand , 65 % NB Sand !PROF Splits: 77 % OA Sand , 9% NB Sand , 14% OB Sand !PROF Splits : 6% NB Sand , 0 % OA Sand , 94% OB Sand !PROF Splits : 0% NB Sand , 10 % OA Sand, 90 % OB Sand !PROF Splits : 100% OA Sand !PROF Splits : 100% A3 Sand !PROF Splits: 2% NB Sand , 98% OA Sand !PROF Splits : 50 % NB Sand , 50 % OA Sand !PROF Splits: 36 % A2 Sand , 52 % A3 Sand , 7 % B Sand , 5% C Sand !PROF Splits: 4% A1Sand ,41 % C Sand , 32 % B Sand , 23 % A3+A2 Sand !PROF Splits: 58% A Sand , 42 % C Sand !PROF Splits: 50 % OA Sand , 50 % OB Sand !PROF Splits: 60 % C Sand , 30% A3 Sand , 10 % A2 Sand , 0% A1 Sand !PROF Splits:60 % TKC 1/TKB7/TKB6/TKB8 Sand s, 30 % TKA4 /TKA 3 Sands, 10 % TKA2 Sands RFT = Reoe ated Forma tion Test RST= Re servior Saturation Tool SZT = Separate Zone Te st WBL= Warmback loq WFL= Water Flow Loq ~ .... -= ("> ~ .... = """" rJ). g """" .... = ~ -- .... = ~ ("> -- Exhibit 6-A ?IVlQ Shut-In Wolle Milne "'nlnt Unit SwName Reservoir API Number Date Shut Reason for Current Mechanical Condition of Future Utility Comments Well Shut-Plans& In ln1 Well includina intearitv issues2 Possibilities• MPB-01 Prince 500292049000 Sep-01 E ESP failed 3 Water source well not currently needed. Evaluate replacing ESP WSW Creek when need arises. MPB-07 Kupar uk 500292132400 Aug-02 D 2 High GOR well. Needs permanent flowlines installed and gas lift Pressure building up slowly. IBP line is blinded. Diagnostics deterrnined potential source of set in well Feb 2006 to secure. pressure from packer leak. Remedial work to secure well olanned. MPB-08i Kuparuk 500292132500 Oct-94 E No known problems 3 Further use as an injector not required. Evaluate potential sidetrack. MPB-11i Kuparuk 500292130500 Apr-07 D TBG leak, well secured w/ sand 1 Need to fix leaking permanent patch, and perform FCO IPIU!I MPB-13 Kuparuk 500292134800 Jun-89 B No known problems. 3 GL well that was shut i n due ta high water cut. Possible channel into water zone. Wellhouse and flowlines removed MPB-17i Kuparuk 500292143400 Apr-98 E No mechanical problems. 3 Wellhouse and flowlines removed. Quick communication with oroducer. Evaluate POtential sidetrack. MPB-19 Kuparuk 500292145100 Jul-91 B 3 Wellhouse and flowlines removed . GL well. High water cut No known problems. producer. Possible frac into water zone. Evaluate potential sidetrack. MPB-23 Kuparuk 500292191500 Jun-01 A No known well integrity issues. 2 High GOR well. Facilities normally cannot handle gas. Would need a TTP pulled prior to Attempted to produce in 2006 but frozen/plugged. Working to bein!I POP'd thaw. MPB-25 Kuoaruk 500292284100 Anr-08 E No known oroblema. 6 Readv to tum on when offset oroducercomes back on (E-18) MPC-09 Kuparuk 500292129900 AU!l-08 D SI, Surf csg leak 3 Intervention under evaluation for 201 o MPC-11i Kuparuk 500292132100 Apr-95 E No wellhouse, no flowlines 3 Further use as an injector not required while no offset oroducera on line. MPC·12Ai Kuparuk 500292137301 Sep-95 D Well suspended 7/13/03. Secured 4 Wellbore lost during coiled tubing sidetrack. with CIBP and FP w ith diesel. MPC-16 Kuparuk 500292136400 May-92 A Well suspended 10/27193. Pulled 4 High GOR from E-03 gas breakthrough. completions and set 2 cement plugs with EZSV retainers over IDArfS. MPC-17i Kuoaruk 500292147300 Mav-00 D Leak in 9 518 " casin!I to surface 6 scooin!I out non-ri!I remedial actions MPC-18 Kuparuk 500292147900 Jul-93 E Well P&A'd 2/1998. 4 No interaction w ith offset producer. MPC-20 Kuparuk 500292191400 Oct-92 B No wellhouse, no flow li nes 3 High water cut. Perf'd without good logs. Wellhouse and flowlines removed. Would need WSO . MPC-25Ai Kuparuk 500292263801 Dec-03 E 3 Shut in well due to rapid/high gas breakthrough in C-07 and C- No known problems 21. Possible Kuparuk or Schrader Bluff sidetrack candidate. MPCFP-02i Kuparuk 500292125800 Nov-95 E No known mechanical problems 3 Thief zone directly to offset producers. Evaluate Sag/Schrader nntential. MPD-01 Kuparuk 500292066400 Dec-90 c Dead ESP completion downhole, 5 No support to block. No flowlines from D pad. Plan to P&A in no suooart to block the future. MPD-02A Kuparuk 500292090001 Aug-99 B Well secured June-05 with 5 High water cut well. No flowlines from D pad. Plan to P&A in the downhole plug. Planned to P&A in 2008 but prQ!lram put on hold. future. MPE-02i Kuparuk 500292141700 Aug-98 E No known problems. Well is 3 No surface facilities. Injector drilled right into a fault. Would secured w/ downhole plug reauire extensive interventions to return to ODAration. MPE-08 Kuparuk 500292215600 Jun-08 D Dead ESP Completion Downhole 2 Awaitin!I Y·Tool Intervention MPE-11 Kuoaruk 500292254100 Dec-08 D Dead ESP Completion Downhole 2 Awaiting RWO for TTC-ESP MPE-18 Kuparuk 500292274800 Feb-08 D No Surface Kit with ESP 3 High WC Well on MPE Pad goes w/o surface kit Completion Downhole MPE-21 Schrader 500292289400 Nov-98 E ESP failed 3 Wellhouse and flowlines removed MPE-33 Schrader 500292289800 Oct-99 c ESP failed; no surface casing and 3 Wellhouse and flowlines removed. Possible conversion to liner has no cement iniection. MPF-17i Kuparuk 500292282300 Dec-05 D Tubing integrity problem 2 RWO needed to replace tubing. Requires new seismic to understand HU connectivitv. MPF-41i Kuparuk 500292277000 Oct-04 E 1 Drilled as a producer. High water saturation so converted to No known problems inj ection. No response seen in offset producer. Evaluate I ootential s idetrack. MPF·74i Kuparuk 500292268200 Feb-08 c Injector, frozen tubing, no other 2 Low value injector, poss ibly return to production 1H 2010. integrity problems. MPF-82i Kuparuk 500292297100 Jan-03 E No known mechanical problems 1 1 Q 2010 Sidetrack planned MPG-OBA Schrader 500292214101 Sep-08 c ESP failed 1 High sand production. Intervention under evaluation for 2010 MPG -11 Schrader 500292278100 Jul-01 c ESP failed 1 MPG -12 Schrader 500292279200 Jul-01 c ESP failed 1 No surface csg. MPH-01 Schrader 500292206100 Oct-98 c ESP failed 1 Well house has been removed MPH-02 Ugnu 500292206200 Nov-01 A No known problems. Has a temp 1 Oil sample retrieved during 2006 but no production to plant drive for ESP MPH-03 Schrader 500292206300 Aug-91 c No known problems. ESP still 1 functional. MPH-09 Schrader 500292280400 May-06 D Hole in casin!I at 311' 2 Redevelopment under evaluation for 201 O MPl-01 Schrader 500292206500 Dec-98 c ESP failed 1 WH and flowlines removed in '98 MPl-12 Schrader 500292303800 Jan-03 c Well cannot be operated with 1 Intervention under evaluation for 2010 current ESP in place. MPl-19 Schrader 500292321800 Dec-08 c ESP failed 6 Intervention under evaluation for 2010 MPJ-07 Schrader 500292219800 Sep-03 c ESP failed 1 9 5/8 surface csg. 7: prod liner. MPJ-09A Schrader 500292249501 Sep-08 D ESP failed 3 High sand production. •Note -W ell s were shut in 100% in 2009 Exhibit 6-A 2009 Shut-In Wells Mi l ne Point Unit Sw Name Reservoir API Number Date Shut Reason for Current Mechanical Condition of Future Utility Comments Well Shut-Plans & In ln 1 Well includina intearitv issues' Possi bilities' MPJ-16i Kuparuk 500292261500 Jan-99 E No known problems 1 No surface facilities. Evaluate potential Sch r ader sidetrack. ESP failed and converted to--------------------------·-·---------------- MPJ-19A Schrader 500292260701 Dec-08 E 6 Convert to injector iniector MPJ-20A Schrader 500292283201 Aug:QJL_ __ E __ Injector with offset J>roducers SI 6 lnj_ector will be put back onl.[n e with offset producers MPJ-21 Schrader 500292282500 Dec-04 c ESP failed. 1 RDS well no surface csg. ------------------------------------------ MPJ-24 Schrader 500292297600 Oct-08 D Downhole fill restricting reservior -2 Intervention under evaluation for 2010 ---·---------------------·-------flow _____ ·-------------------- ---------- MPK-18Ai Kuparuk 500292273301 Dec-08 E Corrosion from source water 1 Intervention under evaluation for 201 O ---------------------------------·-·-· -------------- MPK-21Ai Kuparuk 500292271801 Dec-08 E Corrosion from source w ater 1 Intervention under evaluation for 2010 ·---------------------·-------------------------------·-------- MPK-22i Kuparuk 500292324900 Dec-08 E Corrosion from source water 1 Intervention under evaluation for 2010 ---------------------·-----------------------·--------------- MPK-30 Kuparuk 500292271100 Dec-08 c Failed ESP 1 Intervention under evaluation for 2010 ----·------------------------------------------------------------- MPK-33 Kuparuk 500292272900 Oct-08 c Failed ESP 1 Intervention under evaluation for 2010 --------1 -------·----------------- MPK-34 UGNU 500292271200 Dec-08 E Corrosion from source water Water Source Well WSl/i. ------------------------------------ MPK-43A Kuparuk 500292273801 Sep-08 E Corrosion from source water 1 Intervention under evaluation for 2010 -- - --------------- MPL-01A Kui:>aruk 500292106801 Jan-07 D ESP failed . ------1 Intervention under evaluation for 2010 - Mf'L-10i _ Ku i:>aruk 500292207600 Aug-05 E No known mechanical J:>roblems _ 1 -----Intervention under evaluation for 2010 MPL-17 Kuparuk 500292253900 Apr-00 D ESP failed. Low remaining 1 Low remaining reserves. Evaluate potential gas storage well or reserves --------------Kuparuk sidetrack. ----- MPL-21i Kui:>aruk 500292262900 Oct-98 E High J:>ressure block. --___ 1__ Intervention under evaluation for 2010 MPL-34i -1S!!E>a ru k 500292276600 Oct-06 ____g __ High J>ressure block. ----------.1___ No indication of communicating with surrounding producers. MPL-35A Kuparuk 500292276801 Dec-01 E Sidetrack failed, cemented back. 4 Sidetrack failed and well suspended --------------------- MPL-36 Kuparuk 500292279400 Nov-08 --c ESP failed . Planned to sidetrack ---1 Currently sidetracking with Nordi ~1_. -------- MPL-37A Schrader 500292286401 Nov-99 c Dead ESP , no other mechan ical 1 Surface kit partially robbed ------------issues ; no surface casing_ _____ -------- MPL-39i Kuparuk 500292278600 Jan-99 E No known mechanical problems 2 No surface facilities. Located in isolated fault block, does not ------------------------------sup_11 ort gff!i_et producer~_f lan_JQ fili~t production test. MPL-42i Kuparuk 500292286200 Nov-07 D Slow TxlA communication on gas 1 Intervention under evaluation for 2010 injection MPL-45 Schrader 500292291300 Feb-01 c ESP failed. 1 Low productivity. Evaluate conversion to jet pump or potential Schrader sidetrack. ----------------------·--- MPS-0 1~ Schrader 500292314101 Oct-07 _ -B Well J>roduce @ 100% _'l'_a t~r Clj!_ 1. lntervention __u nder ~valuation for 1_Q1Q_ __________ -MPS-13LS Schrader 500292309380 Oct-08 D Annular communication 1 Intervention under evaluation for 2010 -------------~ ---~---------------· ----------------~----------MPS-13SS Schrader 500292309381 Oct-08 D Annular communication 1 Intervention under evaluation for 2010 ---------·------- No known prob1;;;J,""S - ---- ---- MPS-15i Schrader 500292306100 Aug-05 --E 1 --Intervention under evaluation for 2010 MPS-21i Schrader 500292306500 Oct-05 E No known problems, Cement ove r 1 Lost CT under-reamer in hole I nerforations MPS-22 Ugnu 500292317600 Sep-04 c No known problems 1 Waiting for offset injector to be repaired 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 -Well s we re shut in 100% in 20 09 Section 7 Milne Point Well Testing and ASRC Unit 5 Summary List of Exhibits Well Test Frequency 7-A Milne Point Well Testing Milne Point primarily utilizes on-pad separators for well testing. The pad separators at B, C, E, F, H, K and L pads employ volumetric vessel-based gas-liquid separation, while separators at I, J and S pad employ centrifugal separation. Thus, a variety of metering technologies are employed across Milne Point including: -Turbine positive-displacement or MicroMotion coriolis meters for liquid flow rate -Phase Dynamics watercut meters on the separator liquid legs -Turbine or MicroMotion coriolis meters 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, plus the necessary purge time to flush the lines and vessel. The services of a portable test separator, provided by contractor ASRC, are utilized in areas where no on-pad separator exists,specifically on MPG-pad. MPG-Pad is now fully equipped with an on-pad well testing kit and first commercial 2" Weatherford Alpha "VSRD" (Venturi, Sonar, Red Eye, Densitometer) Multiphase flow meter. The VSRD was installed mid-December 2009 as part of the growing efforts to improve the confidence in test separation systems across BP operations on the North Slope. A Weatherford Redeye meter was installed early 2009 at MPF-pad to help address well testing issues associated with low salinity waterflood breakthrough. Exhibit 7-A provides information on the well tests conducted for consideration in production allocation during 2009. 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 2009 . Exhibit 7-A 2009 Well Testing 2009 Average Tests I Month* Field total all 5.6 KUP all 5.6 SBF all 5.8 SAG all 4.3 Reservoir Pad KUP B 8.2 KUP c 9.3 KUP E 4 .9 KUP F 3.5 KUP H 7.6 KUP J 6.1 KUP K 9.5 KUP L 4.0 SBF c 8.0 SBF E 4.9 SBF G 2.4 SBF H 6.3 SBF I 11.4 SBF J 6 .9 SBF s 4 .8 SAG F 4 .3 *Average Tests I Month calculated as total number of tests divided by (days operating divided by 30.4 days per month). Pad Well Formation ··········-···1 Required i Days On Prod. Tests/ I 1----·---f---......... ~-·······!---·-·--··--t _.!'Yl....Qtlt,.,,h""-+' ----.....! MPB-15 MPB I MPB-16 MPB MPB-20 MPB MPB-21 MPB MPB-22 MPC f MPC-0-1 ·------·+ ----- MPC I MPC-03 MPC MPC MPC MPC MPC MPC MPC p I KUP ! KU KUP ---- ! KUP KUP KUP 179 319 320 115 248 Total Tests 85 Average I Tests I Month* 7.7 7.6 18.7 8.9 8.3 8.1 Milne Point Unit Exhibit 7-A 2009 Well Testing Pad Well Formation Required Tests/ Days On Prod. Total Tests I Average Tests I MPE MPE 358 MPE 0 MPE MPE MPE MPE-11 0 MPE 283 -· _MPE.... I MPE-l? __ _ 2 139 64 0 61 60 0 9 .9 9 .0 6.6 3.3 5.1 0.0 40 4. .. ~::·-+~-~i ~+~--KUP ~+---+----3 ~2 I 5°7 1 -· - -~.·--~-~'~w-~--,+~~~~-----·-'' ·--___ MPE __ ,-J. ••. ...::::....= . ..=-: SBF 2 MPE KUP MPE SBF 2 MPF MPF PF MPF MPF . MPF I MPF-29 I KUP I 1 t ---MPF ! MPF-33A SAG 2 ~PF I MPF-34 MPF I MPF-37 ~-~_:_-_·_--~----~_-:_~--~~-: MPF -1 MPF-50 ~---F-~ MPF-53 F i MPF-54 ' MPF I ~PF-57A -+--- MPF MPF-61 MPF ! MPF-65 KUP KUP KUP 295 353 290 357 357 52 53 61 54 34 54 70 58 56 45 46 47 3 39 ~-F -~6___ l& 39 3.3 29 3.8 3.1 3.5 3.0 2 .7 3.1 2.7 M.PF -f -_M_f'F_:?6A ----~Uf_ _ : •• _l.§~ MPF MPF-69 KUP 1 332 l 34 I 3.1 * . ~:: . I ~::~;: ~~: 1 ~~~ ~~---1:.: I L .. -~f'f _ -~ _M ,PF-80 . I ____ KU ~ L --1 ___ J_ -1~--. -2 --~--·- Milne Point Unit Exhibit 7-A 2009 Well Testing Pad Well Formation PF I MPF-81 I KUP Required Tests/ MPF _ _L_MPF-86 ---t---K_U_P_......,,.... __ -· ~~~---+·--tv1;:;~:: ·I--~~: -··--·~--T-·····--·--····-i--·----+-------' MPF MPF-94 I KUP Days On Prod. Total Tests I Average Tests I * 3 3.0 31 3.5 3.1 I "' --·--·-·-·--+--+------ G MPG-02 I SBF 28 2.4 ----- MPG r·· M PG-Q8A _t_ __ ~l?f --·-~···--····· .::: ... _ . ,;, .. MPG I I MPG MPG-14__j_ __ SBF SBF I MPG ~-+~~- 1... MPG SBF SBF L. ______ __ ~-·· ... ~::-- 2 28 2.4 2.4 2.4 2.3 5.4 314 63 6.1 BF L.......1 0 0 0.0 SBF 2 223 SBF 2 220 SBF 2 0 2 2 2 2 - 2 227 83 2 107 28 2 169 77 2 0 2 2 MPI '--4---...: 3 4 5 _;_4°_ L __ ~!~~ ±_~L - 2 2 348 I 130 I 11 .4 o o I o.o MPI MPI -I , I-350 1 120 __ 1. ___ ~ 2 352 ~ 89 _I 7.7 2 117 25 16:5 r--M'Pj t -'M"PJ --+--- f----- ~~--3 B J I ..... l __ MPT -,~- f MPJ ~--·-····---· ~~~ MPJ MPJ-23 __ SBF 2 I ~:~ J -~:~~~----1--~:: ___ ~~ -1--~ MPJ j MPJ-26 . j ___ SBF _ _j __ _ 6.5 2 I 220 I 45 [ 6.2 1 I 352 !?Q__ -1~ ___ 9_3 _~ 0 0.0 56 . -i-~ 0 I 0.0 -·-·1 --?Q.___ __ __J ___ 5.6 0 29 2.5 34 6.3 2 I 352 2 I O 2 -·---!----- MPK MPK-02 KUP 10.5 MPK I MPK-05 I KUP 12.1 tv1P_K -··1 ···· _tv1_1=:'.IS::Q§__L ____ ~~i:_ -~.........l Milne Point Unit Exhibit 7-A 2009 Well Testing Milne Point Unit Pad l Well I Formation fRequ;rndfDays o;;-1 Total Tests, Tests/ I Prod. I I Tests I onth--J-.·----'" _______ , __ \ __ MQJTI~ KUP 1__ . 333 __ 1_1~----·~-~-Q& I KUP 1 344 125 -·t---11:.Cl KUP 352 5E --·-- 0 0 1 -I l MPL-05 KUP .] •. =t . 321 --i-·3·9 ----~ MPL 3.7 MPL 3.9 MPL ~:~::: ~~: -} T ~±-~~-.. -4.8 MPL MPL-11 ·-~-·+=-1-~-·T_2 06_-+-44 4.4 MPL MPL-12 KUP ......... ..J.---·-··-1-·-·······--l· 250 36 4.4 MPL MPL-13 1. KUP i . 1 355 48 4.1 MPL t=~£L-1j=--i:=--K ~==·=r·----1 --· --359-· 48 4.1 MPL 41 3.5 .MPL-?.Q___J KUP 1 356 MPL -~ MPL-?5 I KUP 1 359 39 3.3 ' KUP 1 299 42 4 .3 MPL I MPL-28 l -·--;·" ~----2o4-~.=-~r --~6 MPL MPL-29 KUP 1 213 MPL MPL-36 KUP 1 0 MPL MPL-40 KUP 1 293 t--~! --1 4.5 MPL MPL-43 KUP 1 318 3.4 '"• _.,,,_-~-~~~-'v·'"~ ~~·-· MPS MPS-01A SBF 2 MPS MPS-03 SBF 2 ,,.,,,. MPS MPS-04 SBF 2 117 MPS MPS-q§_ __ J _SBF···===-2 312 26 -MPS MPS-08 l SBF 2 95 7 2.2 MPS MPS-1 .?..__l __ ......§8-F 2 261 23 2.7 MPS I MPS-17 l SBF 2 134 10 2.3 MPS MPS-19A SBF 2 237 51 6.6 - MPS MPS-23 SBF 2 254 28 3.4 MPS MPS-24 SBF 2 361 90 7.6 MPS MPS-25 SBF 2 322 17 1.6 MPS MPS-27 SBF 2 294 24 2.5 ----·~---· ----·--- MPS MPS-28 SBF 2 353 92 -;:--i -· I MPS MPS-29 SBF 2 336 55 MPS MPS-32 SBF 2 356 75 6.4 ~:} l. MPS-34 SBF 2 309 56 ---~:~ _ _j ----·-~-~ MPS-35 SBF 2 340 63
