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Home My WebLink About2007 Nicolai CreekAurora Gas f LLC www.aurorapower.com May 2, 2008 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7a' Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 0 6 2008 Alaska Oil & Gas Cons. Commission Anchorage RE: Reservoir Surveillance Report and Reservoir Pressure Reports (Form 10-412) Aurora Gas, LLC: Nicolai Creek -South Undesignated and -Beluga Dear Commissioner Seamount: Aurora Gas, LLC hereby submits a Reservoir Surveillance Report and two Reservoir Pressure Reports for the pressures taken in 2007 at Nicolai Creek Unit No. I B, No. 2, and No. 9 gas production wells in the Nicolai Creek Gas Field on the west side of Cook Inlet, as required by Conservation Order No. 478A. Please find enclosed the following information for your files: 1) Reservoir Surveillance Report (Combined for NCU- South and NCU- Beluga); 2) Form 10-412 Reservoir Pressure Report for Nicolai Creek -South Undesignated; 3) Form 10-412 Reservoir Pressure Report for Nicolai Creek -Beluga; 4) Nicolai Creek Unit Pressure Map; and 5) Supporting information including: a) Well bore diagrams for #113 and #9, which are different from those submitted in 2006; b) Post-recompletion Test Summary Reports for #113 and #9 following the 2006 recompletions; c) P/Z vs, Cumulative Production Plots for #1B, #2, and #9. If you have any questions or require additional information, please contact me at (713) 977-5799. Sincerely, AURORA GAS, LLC jEdward Jones President, Engin( enclosures cc: Kristin Dirks, ADNR-DOG Mike Franger, MHT ations 2500 Citywest Blvd., Suite 2500 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 NICOLAI CREEK UNIT WELLS NO. 1% 2, and 9 RESERVOIR SURVEILLANCE REPORT RE: CONSERVATION ORDER NO. 478A H/STORYAND SUMMARY AS OF 12/31/07 BACKGROUND Aurora Gas, LLC re-entered and side-tracked the abandoned Texaco Nicolai Creek Unit (NCU) No. 1A in 2002 and completed the well in three Upper Tyonek sands, the Carya 2-4.2 at 3137-3157' TVD, the Carya 2-5.1 at 3307-3348' TVD, and the Carya 2-6.1 at 3506-3521' TVD. These intervals were commingled upon completion and tested with an AOF of 3.1 MMCfpd. Unfortunately, in spite of free -hanging sand control screens in the completion string, the well produced water and sand along with the gas, and, consequently, has produced very little gas for sales to date, about 1000 mcf. Unable to control the sand production by surface means, the well was recompleted in June of 2006: 1) plugging off the Carya 2-6 sand, from which the sand and much of the water was being produced (as evidenced by sand fill and a "sand -blasted" hole in the screen at that depth), 2) adding perforations to the Carya 2-3 sands at 2783-2864' TVD, the Carya 2-2.2 sands at 2550-2568' TVD, the Carya 2-2.1 sands at 2426-2434' TVD, and the Carya 2-1.2 sands at 2254-2316' TVD, and 3) completing selectively (see attached well bore diagram). As of December 2006, the Carya 2-3 to the Carya 2-1.2 sands are open and producing (perfs at 2307-2918' MD), and the deeper sands, 2-4 to 2-5 (perfs at 3191- 3401' MD) are shut in with a retrievable plug at 3184' in the stinger of the packer at 3145'. These open perfs have produced 255 MMcf of the 263 MMcf produced by this well through 12/31/07. The NCU No. 2 well was also re-entered by Aurora Gas in 2002 and re - completed into the Upper Tyonek Carya 2-1.1 sand at 2141-2177' TVD, the Carya 2-1.2 sand at 2342-2354', and the Carya 2-2.1 sand at 2493-2511' TVD. These commingled intervals tested for a calculated AOF potential of 14.6 MMcfpd. A production facility and gathering line were constructed in 2003 and the well started producing to sales December 2003. The well has produced 690 MMcf thru 12/31/07. The NCU No. 9 was drilled on the same pad as the two directional wells above in 2003 to capture reserves behind two strings of pipe in the two old wells. It was completed in a Beluga Tsuga 2-7 interval at 1320-1447' TVD/MD (now the Middle Completion). This well tested yielding at calculated AOF potential of 49.1 MMcfpd. It also started producing to sales in December 2003 and produced 1071 MMcf from this Completion. Because this completion has depleted significantly, a recompletion adding additional Tsuga 2-8, 2-7, and 2-6 sands from 1148-1904' was completed in September 2006. The well is now producing from the Lower Completion at 1552-1904' (9 different Tsuga 2-7 and 2-8 sands). This Lower Completion has produced 235 MMcf thru 12/31/07 of the 1306 MMcf total produced from this well bore. NOTE: All three of the above well are on the same pad, with the # 1 B and #2 being directional, so all have the same ground level elevation (22' AMSL) and nearly the same KB/DF elevation, so TVD's are very nearly TVDss and, thus, almost directly correlative. CONSERVATION ORDER NO. 478A REQUIREMENTS This Order issued October 16, 2003, by the AOGCC has three items pertaining to reservoir surveillance at Nicolai Creek Unit wells No. 1B, No. 2, and No.9, requiring: 1) (#3) Initial reservoir pressures, 2) (#4) Annual monitoring of reservoir pressures, and 3) (#5) Annual reservoir surveillance reports. INITIAL RESERVOIR PRESSURES Form 10412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2002 and 2003, show initial reservoir pressures. The initial reservoir pressures for #I B and #2 were obtained by bottom -hole pressure surveys (No. 1B and 2) and confirmed by quartz -crystal surface pressures extrapolated to subsea datum. These initial pressures were: #1B-1625 psig at -3293' TVDss, and #2-1025 psig at -2285' TVDss. The #9 well was taken by quartz -crystal surface pressure recorder and was confirmed by open -hole MDT measurements—it was 673 psig at -1348' TVDss. Subsequent work, i.e., the 2006 recompletions of #IB and #9, has added the following original pressures (see attached 2006 Well Test Summaries for both wells): 41B-1211 psig at -2537' TVDss (commingled currently open perfs of Carya 2-2.1 to the 2-3 at 2480'- 2918' MD) and in #"66 psig at -1706' TVDss (Lower Completion). ANNUAL MONITORING OF RESERVOIR PRESSURES Attached are Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2007, showing annual reservoir pressures, along with some comments. Surface pressures have been used exclusively for annual pressures after initial pressures in Wells #2 and #9, which have made very little water, so they are consistently in single-phase condition. Surface pressures in #113 maybe affected by some minor buildup of water in the wellbore, so a bottom -hole pressure was obtained on 9/12/07. Note that due to the recompletions of #IB and #9 in 2006 and the subsequent production of different intervals, the datum TVDss's for these wells have changed since the 2006 submittal. The reservoir pressure survey data and production data from the three producing wells have been plotted to yield P/Z vs. Cumulative Production curves, providing a material - balance projection of reserves. Those plots (using Ryder Scott Excel templates) are attached. These show the the #113 having an EUR of 512 MMcf from the open perfs, of which 255 MMcf were produced thru 12/31/07. The #2 is shown to have an EUR of 871 MMcf, assuming 3 -stage compression (now installed), of which 690 MMcf had produced thm 12/31/07. The Middle Completion of the #9 is given an EUR of 1370 MMcf, of which 1071 MMcf had produced thru 12/31/07—this interval is now shut in. The Lower Completion in the #9 is shown to have an EUR of 671 MMcf, of which 235 MMcf were produced thru 12/31/07. (Note that the only pressure used in this latter P/Z vs. Cum. Production plot is the p• calculated from a (surface) pressure buildup test in August 2007). The recompletion of the NCU #1B in June 2006 provided additional pressure information of some of the Upper Tyonek Carya sands that have been producing in the #2 well. This pressure data from the tests indicates that there is no depletion of these zones in the No. 1B from the No. 2 production. In particular, the Carya 2-1.1, 2-1.2, and 2-2.1 are commingled in the #2 and had an initial SIBHP at -2285' TVDss of 1025 psig. The comparable zones in the #1B, commingled 2-2.1 and 2-2.2 and the 2-1.2 had bottom -hole SIP's estimated at 1045 and 1040 psig at datum of -2484' and -2272' TVSss, both close the the original pressure in #2 and much higher than the then most recent SIBHP's of 221 prig at -2285'. This indicates that there is a geological barrier and no communication between the two well bores. POOL PRODUCTION ALLOCATION FACTORS The production from NCU 1 B, 2, and 9 is metered several times and allocated back to each well on the basis of these meters. Each of the three wells has an individual separator into which the well flows, eliminating any free water from the flow stream, then immediately downstream of the separators, each well is individually metered. The flow from the three wells may be combined at this point and then compressed before going thru the glycol dehydration system. After dehydration, the combined flow from these three wells is metered again before going into the gathering system. The gathering system takes the gas to the CIGGS Meter 6103/8103 where it is joined by the flow from NCU #3 upstream of the sales meter. It is metered before being commingled into flow going into the Marathon -operated CIGGS pipeline system. The total sales volume through this meter is allocated back to each well proportionally based on the individual well meter volume divided by the sum of all the wells meters' volumes minus lease -use gas, where lease -use (fuel) gas is allocated proportionately to each well at a facility. RESERVOIR DEVELOPMENT AND DEPLETION PLANS NCU 1B-- As mentioned previously, the #1 B was worked over in June 2006: the Carya 2-6 perfs were plugged off (with a cement retainer set above them at 3500' MD) and the Carya 2-3, 2-2.2, 2-2.1, and 2-1.2 sands perforated and tested. Packers were set between the 2-4.2 and 2-3 perfs, between the 2-3 and the 2-2.2, and between the 2-2.1 and 2-1.2 sands. Due to water and sand production from the Carya 2-4.2, and 2-5.1 sands which were open to production immediately following the 2006 recompletion, a retrievable plug was set just beneath the packer at 3145', between the 2-3 and 2-4 sands to shut off the lower sands. The 2-1.2 thm 2-2.2 sands are all isolated by packers, but the sliding sleeves are open at this time. (See the Current Configuration Well Bore Diagram attached). Thus, all the intervals between 2307' and 2918', Carya 2-1.2 to 2-3 sands, are open to production at this time. When these sands deplete and a water disposal well is active (the permitted Aspen #1), Aurora plans to go back to the deeper sands in the Carya 2-4 and 2-5. No additional development in this well bore is anticipated. In February 2008, the well produced for 7 days and averaged 495 mcfpd at 120 psi. NCU #2—This well is producing with a booster compressor, giving it 3 stages of compression, and is expected to produce to depletion in the near future. It has (as of 12/31/07) produced 690 MMcf of the 871 MMcf EUR and is producing at 592 mcfpd at 20 psi in March 2008 (average for 14 days on). No additional development is anticipated in this wellbore, as the only remaining apparently productive sands are behind two strings of casing in #2 and are available in the #9 well bore. NCU #9—The workover of this well in mid September 2006 added perforations to the Beluga section (unique to #9) both below and above the existing perforations. Three packers were run in the well to isolate the existing perfs from those above and below until pressures have equalized (see NCU 9 Wellbore Configuration attached). The Lower completion is now being produced, averaging 330 mcfpd at 110 psi for 12 days in March 2008. The Upper Completion will be opened and commingled with the Lower when pressures equalize, and finally, when the Upper and Lower pressures are close to the current pressure in the Middle completion, the sliding sleeve isolating those perfs will be opened and that zone commingled with the others. (This Middle completion is has produced 1071 of the expected 1370 MMcf EUR and was producing about 600 mcfpd at 140 psi before the recompletion). Following the workover, this well bore still has 8 potential Beluga Tsuga 2-5 and 2-6 sands between 668' and 1054' that have apparent gas production potential. These sands were completed at the time of the 2006 recompletion workover for 2 reasons: 1) the large pressure differential expected between these shallow sands and the deeper ones, and 2) the cement bond log indicates a top of cement at 840', so remedial cementing will be required for the shallower sand completions. Thus, at least one more recompletion workover is expected in the life of this well bore. No additional development of either Pool is anticipated, as the Pools (and PA's) are now outlined. However, planned extension drilling in the Field (the #11 and #12 locations) may extend these Pools. RESERVOIR PRESSURE MAP AT DATUM Because each well had its individual reservoirs, a reservoir pressure map at datum seems to be irrelevant. However, now that there are some common sands open in the #1B and #2 it may have more relevance, although the sands are apparently not continuous between wells. Attached is a pressure maps of the Nicolai Creek --South Undesignated Pool and the Nicolai Creek—Beluga Pool, showing initial and current pressures at the several pertinent subsea Data. Ed Jones (4/30/08) J N # Z w D � d y m d p Q O 0 c w H N m m J Z O N d N N O <m O O N W N xn G 0 O (O A S m 00 00 3 l O _ n O N d O ON O i d d � A 0 O � � o _ m S (n v F m m ci O O N 3 O O O n N N N 3 p 5D= N d C N d N Z A = a O) O 3 v m 3 P o T N m p n 2s = n O O N 3 F O N d N ry ry p N P wV � O O = m o OJo• C 3 a 3 3 o_ T nNi in N = d N p U1 W 0' _ � y Q V N S Q N 41 (O Z Of (� O �• A\� m O 3 m D O x d d d — a m v m a C N V N V � C N < W V fp A C d N N out o 0 W A n m Cp 0 o W v d m N ''mAA v' m 0 _ T N m ChN m X 0 D 'D^ V' _o r D Z 0 G) D 0 O Z U) m D O Z 0 O U) U) O z C0 D m O n D D ►1\ �\ /}\}}} C: C) )/ [( )! 4 \\ \cn\ \\ \) (} }{ \\ !` }}(\ ( )) ;; } » / \ � /3 \cR ! \ \ - \ ( � /}\}}} C: C) )/ [( )! 4 \\ \) }}(\ )) ;; \\22 E3 /3 \cR Aurora Gas, LLC Nicolai Creek Unit No. 1-B Current Configuration (12116/06) 2-7/8" 6.5 # J-55 the to surface 13 3/8" 54# J-55 Surface Csg at 1,904'. Cmtd to surface w/ 1,530 ss "G". Carya 2-1.2 Perfs: 2,307'-2,326 , ,307'-2,326' MD 2,350'-2,370' MD (TVD 2,254'- 2,316') Carya 2-2.1 Perfs: 2,480' -2,486' MD (TVD 2,426'- 2,434') Carya 2-2.2 Perfs: 2,604'- 2,622' MD (TVD 2,550'-2,568') Carya 2,3 Perfs: 2,837'-2,842' MD 2,862'- 2,867' MD 2,913' - 2,918' MD (TVD 2,783'- 2,864') Carya 24.2 Perfs: 3,191'- 3,21 P MD (TVD 3,137'- 3,157') Carya 2-5.1 Perfs: 3,371' -3,401' MD (TVD 3,307'- 3,348') Carya 2-6.1 Perfs: 3,560'- 3,575' MD (TVD 3,506'- 3,52 F) Float collar @ 3,604' MD Float shoe @ 3,648' MD TO @ 3,672' MD (3,617' TVD) Drilled 26" Hole 20" 94# H40 Conductor set at 232, Cmtd to surface - w/3W sx "G". Drilled 17 la" Hole u Sliding Sleeve w/ X -profile @ 2,268' G-77 Packer @ 2,280' (Closed) Sliding Sleeve w/ X -profile @ 2,375' G-77 Packer @ 2,440' (Open) yI Sliding Sleeve w/ X -profile @ 2,742' Jl+ G-77 Packer @ 2,765' (Open) X -nipple @ 2,775' VTA Packer @ 3,145' /'. XN Nipple @ 3,184' (plugged) Well completed with sand exclusion screens across the indicated perforations. iCement Retainer @ 3,500' 7" 234 J-55 Production Csg @ 3,650'MD (3495' TVD). Cmtd to surface w/ 82 bbls "G" lead at 124 ppg and 67 bbls "G" tail at 15.8 ppg. Fairweather E&P Services, Inc. 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Data 0EUR=512 ♦OGIP=577 CUM PROD, MMcf LSMF Include? (YIN) ,000 1 6/812007 1,038 1,1020.8755 1,258 0 n 2 800 656 95 y 3 5/19/2007 515 544 0.9341 583 159 600 4 6/1212005 535 565 0.9317 607 175 Y 5 alf>/2007 363 383 0.9530 400 225 n 6 911212007 438 0.9465 463 226 y 200 9/1212007 392 413 0.9494 435 O n 8 12/1/2007 315 332 0.9591 346 0 n 100 200 300 400 500 600 700 Cumulative Production, MAId POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z SHP2, Psla CUM PROD, MMcf LSMF Include? (YIN) 1 6/812007 1,038 1,1020.8755 1,258 0 n 2 211012007 575 608 0.9268 656 95 y 3 5/19/2007 515 544 0.9341 583 159 y 4 6/1212005 535 565 0.9317 607 175 Y 5 alf>/2007 363 383 0.9530 402 225 n 6 911212007 438 0.9465 463 226 y 7 9/1212007 392 413 0.9494 435 226 n 8 12/1/2007 315 332 0.9591 346 256 n Point 3 is still building. Point 5 is from SPIDR and still building Water in well bore? Point 6 is from bhp survey—however, sand in tubing above tower Paris Point 7 is from surface pressure at the time of the BHP survey for Point 6. Water in well bore? These results were prepared using Ryder Scott'�Gas Material Balance. This is not Ryder Scott work product. 100 200 300 400 500 600 700 800 900 1,000 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psla BHP, Psia Z BHP/Z, Psia CUM PROD, MMof LSMF Include? (Y/N) Data O • EUR = 871 ♦ OGIP 1 11/21/2003 1,016 ♦ LSMF Excl. Data = 913 0 n 2 11/22/2003 1,200 1,058 0.8736 1,211 2 n 3 1.000 1,004 1,060 0.8734 1,214 2 N 4 2/11/2004 766 807 0.90D4 896 142 y 5 6/15/2004 555 584 0.9264 630 267 800 6 7/152004 595 626 0.9213 680 270 y 7 12/312004 385 404 0.9483 427 461 n 8 4/302005 395 415 0.9470 438 470 n 9 7/16/2005 415 436 0.9444 462 472 y 600 21172006 225 O 0.9695 244 554 n 11 9/142006 168 176 0.9772 180 609 n 12 10/32006 195 204 0.9736 210 400 N 13 121312006 240 252 0.9675 260 624 N 14 1/182007 255 268 0.9655 277 624 N 15 2/42007 275 289 200 300 624 n 16 3/82007 O 3151 0.9595 328 624 0 17 007i 295 310 0.96021 3231 630 Y 18 8/11/2007 100 200 300 400 500 600 700 800 900 1,000 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psla BHP, Psia Z BHP/Z, Psia CUM PROD, MMof LSMF Include? (Y/N) 1 11/21/2003 1,016 1,073 0.8721 1,230 0 n 2 11/22/2003 1,002 1,058 0.8736 1,211 2 n 3 1112212003 1,004 1,060 0.8734 1,214 2 N 4 2/11/2004 766 807 0.90D4 896 142 y 5 6/15/2004 555 584 0.9264 630 267 N 6 7/152004 595 626 0.9213 680 270 y 7 12/312004 385 404 0.9483 427 461 n 8 4/302005 395 415 0.9470 438 470 n 9 7/16/2005 415 436 0.9444 462 472 y 10 21172006 225 236 0.9695 244 554 n 11 9/142006 168 176 0.9772 180 609 n 12 10/32006 195 204 0.9736 210 609 N 13 121312006 240 252 0.9675 260 624 N 14 1/182007 255 268 0.9655 277 624 N 15 2/42007 275 289 0.9629 300 624 n 16 3/82007 300 3151 0.9595 328 624 Y 17 007i 295 310 0.96021 3231 630 Y 18 8/11/2007 287 301 0.96131 3131 647 Y These results were prepared using Ryder ScotfsCas Material Balance. This is not Ryder Scott work product. - COUNN, STATE: _ RESERVOIR: - ---- ND, FEEEET: COND. CORR? (YIN): 800 700 600 500 a jj 400 a x m 300 200 100 0 0 Reservoir __ . _. .. - Keret Borough. West Side Cook Inlet, Alaska - _ _ OttOe 1. (Pabtie) 200 400 600 800 1,000 1,200 1,400 1,600 1,800 2,000 Cumulative Production, MMcf POINT NUMBER DATE ♦ LSMF Data o Exd. Data • EUR = 1,644 ♦ OGIP =1,739 BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SRP, Psia BHP, Psia Z Psia MMC/ Include? (Y/N) f iT.- 9/222003' 877! 0.9086' 745 -__..._ —__..._.. 0( n 2 11/202003; 6671 688! 0.8072 759! 3 _ 2/11/2004! -- 588~-- 605'---- a 659! 108, y 4 6/7820041 5151 5311 0.9275, 5731 310! 5 C 12/312004 405! 417; 0.94271i4431 6661 n 6 4/30/20051 420! 4331, 0.9406 4I 680! n 7 7/1820051 435, 448; 0.93851 478 682! Y 8 2/17/20061 325' 335! 0.9538 351 0 - Y 9 9/122006, 1731. 1791 0_97521 183 1 068: n _.____ �_._._........ —1_ ---------- _ -_. 200 400 600 800 1,000 1,200 1,400 1,600 1,800 2,000 Cumulative Production, MMcf POINT NUMBER DATE BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SRP, Psia BHP, Psia Z Psia MMC/ Include? (Y/N) f iT.- 9/222003' 877! 0.9086' 745 -__..._ —__..._.. 0( n 2 11/202003; 6671 688! 0.8072 759! 3 _ 2/11/2004! -- 588~-- 605'---- 0.9179 -- 659! 108, y 4 6/7820041 5151 5311 0.9275, 5731 310! 5 C 12/312004 405! 417; 0.94271i4431 6661 n 6 4/30/20051 420! 4331, 0.9406 4I 680! n 7 7/1820051 435, 448; 0.93851 478 682! Y 8 2/17/20061 325' 335! 0.9538 351 864 Y 9 9/122006, 1731. 1791 0_97521 183 1 068: n _.____ �_._._........ —1_ ---------- _ -_. I .Point ! Point 1 is bhp from open -hole MDT. i — Point 2la surface pressure measured by testers before 4 -point lest Poiint 3 is surface pressure from crystal pressure recorder. Pant 4 is gauge pressure. Points 5, 6, and 7 is tree gauge pressure after long-term SI (4/1/05) 'Pant 8 is tree gauge pressure after 28 hr SI - snot IPoint 9 is short-tim shut just before recon letion likely built up to static. nstallatioio,n _... ...... ol. __-_ pmmrlsassumed ! These results were prepared using Ryder Scotts Gas Material Balance. This is not Ryder Scott work product. I'D 100 200 300 400 500 600 700 800 Cumulative Production, Illlllld POINT NUMBER (Automatic) DATE (Optional) I SITP, Pala BHP, Psis Z BHP/Z, Pala CUM PROD, MMd LSMF Include? (Y/N) ♦ LSMF Data 0 6cd. Data • EUR = 671 ♦ OGIP = 702 10 1 9/26/2006 650 676 0.9139 739 10 n 2 2/10/2007 435 452 0.9414 480 94 n )D 5/1/2007 505 525 0.9323 563 109 n 4 7/16/2007 475 493 0.9362 527 159 n 5 8/11/2007 637 0.9186 )0 163 y 6 9/252003 810 0.8981 902 0 y 7 O 404 0.9475 426 163 n 8 11/62007 385 400 O 422 208 n 30 O O )0 Pam 5 is p' from surf pressure buildup measure by SPIDR Point 6 is original MDT data avg gradient from 1832' and 1438' )0 )0 )0 0 100 200 300 400 500 600 700 800 Cumulative Production, Illlllld POINT NUMBER (Automatic) DATE (Optional) I SITP, Pala BHP, Psis Z BHP/Z, Pala CUM PROD, MMd LSMF Include? (Y/N) 1 9/26/2006 650 676 0.9139 739 2 n 2 2/10/2007 435 452 0.9414 480 94 n 3 5/1/2007 505 525 0.9323 563 109 n 4 7/16/2007 475 493 0.9362 527 159 n 5 8/11/2007 637 0.9186 693 163 y 6 9/252003 810 0.8981 902 0 y 7 8/11/2007 389 404 0.9475 426 163 n 8 11/62007 385 400 0.9480 422 208 n Pam 5 is p' from surf pressure buildup measure by SPIDR Point 6 is original MDT data avg gradient from 1832' and 1438' These results were prepared using Ryder Scott'aGas Material Balance. This is not Ryder Scott work product. NICOLAI CREEK FIELD SOUTH UNDESIGNATED & BELUGA POOLS NCU-9 TSUGA GAS EXTENT —80 ACRES SEC 30 DATUM -2285' TVDSS INITIAL — 1041 psig 9/2007 — 396 psig (oastfitte DATUM -2537' TVDSS INITIAL — 1211 psig 9/2007 — 403 psig NCU1 1/4 MILE r— to NCU 6 DATUM -1706' TVDSS INITIAL — 666 psig 8/2007 — 403 psig i i -228: NCU-2 CARYA GAS EXTENT —144 ACRES Aurora Gas, LLC SEC 29 1 DATUM -2285' TVDSS INITIAL — 1025 psig 8/07 — 301 psig 7 1 \ NCU TYONEK PA NCU 4