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Home My WebLink About2008 Nicolai CreekAurora Gas, LLC www.aurorapower.com October 8, 2009 Mr. Steve Davies Alaska Oil and Gas Conservation Commission 333 W. 7"Avenue, Suite 100 Anchorage, AK 99501-3560 RE: 2008 Nicolai Creek Reservoir Surveillance Report Dear Mr. Davies: Attached, please find the Reservoir Surveillance Report for the Nicolai Creek field. If you have any questions, please either myself or Ed Jones at the Houston telephone number below. Sincerely, Bruce D. Webb Manager, Land and Regulatory Affairs attachment 1400 West Benson Blvd., Suite 410 -Anchorage, AK 99503 • (907) 277-1003 . Fax: (907) 277-1006 6051 North Course Drive, Suite 200 • Houston, TX 77072 . (713) 977-5799 • Fax: (713) 977-1347 NICOLAI CREEK UNIT WELLS NO. 1131 2, and 9 RESERVOIR SURVEILLANCE REPORT RE: CONSERVATION ORDER NO. 478A HISTORY AND SUMMARY AS OF 12/31/08 r;Y.Ty;t"3llijaE 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, produced very little gas for sales to date. 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 were mechanically open and producing (perfs at 2307-2918' MD, but some now plugged by sand --see note below Development plans), 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 281.6 MMcf of the 289.2 MMcf produced by this well through 12/31/08. The NCU No. 2 well was also re-entered by Aurora Gas in 2002 and re - completed into the Upper Tyonek Carya 2-L I 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 729.2 MMcf since the re-entry thru 12/31/08. 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 produced 326 MMef from the Lower Completion at 1552-1904' (9 different Tsuga 2-7 and 2-8 sands) between the recompletion in October 2006 and October 2008. In October 2008, the pressure of this Lower Completion had declined to near that of the Middle Completion, so the sliding sleeves for the Middle Completion were opened, allowing both the Middle and Lower Completions to produce commingled. The well has produced 1485.8 MMcf thru 12/31/08 of which 346 MMcf is allocated to the Lower Completion and 1113 MMcf to the Middle Completion. NOTE: All three of the above well are on the same pad, with the 4113 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. 113, No. 2, and No.9, requiring: 1) (0) Initial reservoir pressures, 2) (#4) Annual monitoring of reservoir pressures, and 3) (#5) Annual reservoir surveillance reports. INITIAL RESERVOIR PRESSURES Form 10-412'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 #1B 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: #113-1625 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 #113 and #9, has added the following original pressures (see attached 2006 Well Test Summaries for both wells): #1B-1211 psig at -2537' TVDss (commingled currently open perfs of Carya 2-2.1 to the 2-3 at 2480'- 2918' MD) and in #966 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 2008, showing annual reservoir pressures, along with some comments. Surface pressures have been used exclusively for annual pressures after initial pressures in Wells #2 and 99, 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, but no bottom -hole pressures were obtained in 2008 due to the low volumes produced. Note that due to the recompletions of #113 and #9 in 2006 and the subsequent production of different intervals, the datum TVDss's for these wells have changed since the 2006 submittals. 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 #1B having an EUR of 440 MMcf from the open perfs, of which 282 MMcf were produced thru 12/31/08. The #2 is shown to have an EUR of 942 MMcf, assuming 3 -stage compression (now available), of which 729 MMcf had produced thru 12/31/08. The Middle Completion of the #9 is given an EUR of 1776 MMcf, of which 1113 MMcf had produced thru 12/31/08—this interval is now commingled with the Lower Completion, which is shown to have an EUR of 547 MMcf, of which 346 MMcf were produced thru 12/31/08. The recompletion of the NCU #113 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. 1 B 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' TVDss, both close the the original pressure in #2 and much higher than the then most recent SIBHP's of 221 psig 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 113, 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—This well produced 26.3 MMcf in 2008, producing for 74 days and averaged 355 mcfpd at 80 psi last FTP. In October 2008 a slick -line baler was run to check for sand fill and cleanout the tubing, as the well had been producing some sand. It was discovered that the well had significant sand fill, and in fact, the well was left with fill in the tubing at 2660', which left only the top production sliding sleeve open—thus, only the Carya 2-1.2 perfs at 2307-2370' are open and capable of production. (See attached wellbore diagram and Monthly Production History spreadsheet). Therefore, Aurora plans thru-tubing work to clean out the well and install additional sand control. This work will be deferred until 2010 or when the market demand increases to justify the costs. NCU #2—This well has produced with a booster compressor, giving it 3 stages of compression, but at this point is hasn't increased the rate significantly. It has (as of 12/31/08) produced 729 MMcf of the 942 MMcf EUR and was producing at about 150 mcfpd at 135 psi in March 2009 (average for 31 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. However, the reservoirs in this well are being investigated for gas storage. (Note that the SIP's and consequently the EUR from the P/Z increase when the well is shut-in for long periods of time, as the less -depleted low -perm sands in the deepest perforated interval or far from the well bore in other intervals continue to contribute gas and pressure to buildup). NCU #9—On October 29, 2008, the Middle Completion (the original producing interval --see NCU 9 Wellbore Configuration attached) was opened to be commingled with the Lower Completion. The Lower Completion still apparently had higher SI BHP than the Middle Completion (estimated at 270 psia vs. 179 psia), but the surface flowing pressures were comparable (80 psig for the Lower vs. 140 psig for the higher when it was SI in 2006). The commingled completions now being produced an average of 1277 mcfpd at 140 psi for 31 days in March 2009. The Upper Completion will be opened and commingled with the Lower and Middle completions when pressures equalize, by opening the sliding sleeve isolating those perfs. Following the 2006 recompletion 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 not 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, extension drilling in the Field, Nicolai Creek #11, is just completed, and the results are being evaluated (October 2009). Creation of a new PA or expansion of one of the existing ones will likely be proposed. 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 #113 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. 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N N O � O 0 0 0 N N 1V1 1 V 0 C o N E N y = n v O U O \ � \V � OI C N C w � C a O d Np J j o O N Oo N F Q t `o m p o n m v d y) m o+ c U c O m C d V W « d E U J c m C O J p d _ d n r V ty � N t m d d c m d N r a m a E a E 3 _ d m ii d m o c u w Z O O N W O C d d d OI & 3 C d p W N r Q N Q F Z c m 7 a d d z o « Z a a LLcc w w JE n d m c _ a O < N _ RESERVOIR: Wichert-Aziz correction for WELLHEAD TEMP, °F: ioTTOMHOLE TEMP, 'F: COND. CORR' Corrected_ Corrected" Pi 1,400 1 1 0.3b N 340.81 0 KYder Scott 200 I LSMF Data Excl. Data 0EUR=440 ♦OGIP=496 Reservoir � Lj Solutions (� (Public) �s \ (Protected) Least Squares Mean Fit Results ucept, BHP/z 852 MMCF 496 MMCF - 440 very Factor _ 0.8871 0 100 200 I LSMF Data Excl. Data 0EUR=440 ♦OGIP=496 200 500 600 Cumulative Production, MMcf 000 DATE BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SITP, Psia BHP, Psia 800 Z Psis MMcf Include? (YIN) 600 6/6/2006 1,038 1,1_02 1,258 0 n 2 2/10/2007 575 608 _0.8755 _0.9268 656 95 y 3 5/19/2007 515 644 d 400 _159 y 4 8 535 A 0.9317 175 Y 5 _/12/2005 8/6/2007 363 200 0.9530 _607 402 225 n 6 9/12/2007 438,I –-0.9465 463 - 226 Y Y _ t, 0 9112/2007 392 413 0.9494 435 226 0 100 200 300 400 500 600 Cumulative Production, MMcf POINT NUMBER DATE BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SITP, Psia BHP, Psia Z Psis MMcf Include? (YIN) 1 6/6/2006 1,038 1,1_02 1,258 0 n 2 2/10/2007 575 608 _0.8755 _0.9268 656 95 y 3 5/19/2007 515 644 _ 0.9341 _ __583 _159 y 4 8 535 565 0.9317 175 Y 5 _/12/2005 8/6/2007 363 _ 383, 0.9530 _607 402 225 n 6 9/12/2007 438,I –-0.9465 463 - 226 Y _ 7 9112/2007 392 413 0.9494 435 226 n 8 12/1/2007 315 _ 346 256 n 9 5/29/2008 345 _332 364 _0.9591 0.9554 381 261 Y 10 5/21/2009 328 346 0.9574 361 282 Y 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 lower perfs 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's Gas Material Balance. This is not Ryder Scott work product. FIELD: NICOLAI CREEK 400 600 800 Cumulative Production, MMcf Reservoir ,200 COUNTY, STATE: TI 1N, R12W SM, Kenai Borough, West Side Cook Inlet, Alaska Solutions RESERVOIR: Upper Tyonek, 2426-2916' MD BHP/Z, (Public) LSMF ' Wichert-Aziz correction for contaminants, if any (Optionap (Protected) BHP, Psia WELLHEAD TEMP, °F: 45.0 SOUR GAS MOLE % Least Squares Mean Fit Results BOTTOMHOLE TEMP, °F: 77.0 N2 1.06 Y -Intercept, BHP/z 977 WET GAS GRAVITY: 0.5607 CO2 0.00 OGIP, MMCF 988 TVD, FEET: 2,309 H2S 0.00 800 1.211 COND. CORR? (YIN): N 3 EUR, MMCF 942 Corrected" Tc, °R: 343.70 1.214 Recovery Factor 0.9538 Corrected' Pc, Psia: 671.82 766 BHP/z @ Abandonment 45 1,400 0 200 400 600 800 Cumulative Production, MMcf - LSMF Data Excl. Data • ELF = 942 ♦ OGIP = 988 ,200 1,200 POINT NUMBER DATE BHP/Z, CUM PROD, LSMF 000 (Optionap SITP, Psia BHP, Psia Z Psia MMcf Include? (Y/N) 1 11/21/2003 1,016 1,073 0.8721 1,230 0 n 2 11/22/2003 1.002 1,058 800 1.211 2 n 3 11/22/2003 1,004 1.060 0.8734 1.214 2 N 4 2/11/2004 766 807 ♦ 896 142 y 5 600 555 0 0.9264 630 267 N 6 7/15/2004 595 626 0.9213 680 270 400 7 12/31/2004 385 404 0.9483 427 461 n 8 4/30/2005 395 415 0.9470 438 470 n 9 `Y r. 415 436 0.9444 462 472 y 10 2/17/2006 225 200 0.9695 244 554 n 11 9/14/2006 168 176 0.9772 180 609 n 12 0 195 204 0.9736 210 609 N 0 200 400 600 800 Cumulative Production, MMcf 1,000 1,200 POINT NUMBER DATE BHP/Z, CUM PROD, LSMF (Automatic) (Optionap SITP, Psia BHP, Psia Z Psia MMcf 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 11/22/2003 1,004 1.060 0.8734 1.214 2 N 4 2/11/2004 766 807 0.9004 896 142 y 5 6/15/2004 555 584 0.9264 630 267 N 6 7/15/2004 595 626 0.9213 680 270 y 7 12/31/2004 385 404 0.9483 427 461 n 8 4/30/2005 395 415 0.9470 438 470 n 9 7/16/2005 415 436 0.9444 462 472 y 10 2/17/2006 225 236 0.9695 244 554 n 11 9/14/2006 168 176 0.9772 180 609 n 12 10/3/2006 195 204 0.9736 210 609 N 13 12/31/2006 240 252 0.9675 260 624 N 14 1/18/2007 255 268 0.9655 277 624 N 15 2/4/2007 275 289 0.9629 300 624 n 16 3/8/2007 300 315 0.9595 328 624 Y 17 4/30/2007 295 310 0.9602 323 630 Y 18 8/11/2007 287 301 0.9613 313 647 Y 19 5/29/2008 124 130 0.9832 132 712 n 20 1/31/2009 255 268 0.9655 277 729 Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WtLI NAML: PQUUL l UNLLK UNI1 NU. B 1,400 Kyder Scott H FIELD: _ _NICOLAI CREEK Reservoir =�r� COUNTY, STATE: T1IN. R1 2W SM. Kenai Borough. West Side Cook Inlet, Alaska Solutions (Automatic) RESERVOIR: Beluga 1320-1447' BHP, Psia (Public) Psia ichert-Aziz correction for contaminants, it any MMcf (Prcrected) 1 WELLHEAD TEMP, °F: 40.0 SOUR GAS MOLE% Least Squares Mean Fit Results TTOMHOLE TEMP, °F: 66.0 Nr 0.89 Y -Intercept, BHP/z 719 WET GAS GRAVITY: _ 0.5633 co, 0.35 OGIP, MMCF 1,879 ND, FEET: 1,384 H'S 000 6/18/2004 515 531 0.9275 GOND. CORR? (Y/N): N y EUR, MMCF 1.776 Corrected' Tc, °R: 343.86 666 Recovery Factor 0.9452 Corrected- Pc, Psia: 672.10 500 BHP/z @ Abandonment 41 0 200 400 600 800 1,000 1,200 Cumulative Production, MMcf 1,400 1,600 1,800 2,000 �- LSMF Data Excl. Data ♦ EUR = 1.776 ♦ OGIP = 1.879 700 BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SITP, Psi. BHP, Psia Z Psia MMcf Include? (Y/h 1 9/22/2003 677 0.9086 745 0 n 2 11/20/2003 667 688 0.9072 759 0 800 3 2/11/2004 586 605 0.9179 659 106 y 4 6/18/2004 515 531 0.9275 573 310 y 5 12/31/2004 405 417 0.9427 443 666 n 6 4/30/2005 420 433 0.9406 500 680 n 7 7/16/2005 435 448 0.9385 478 682 Y 8 2/17/2006 325 335 0.9538 351 864 Y 9 9/12/2006 173 179 0.9752 183 1,068 n 10 400 234 1,228 0 11 9/2/2009 255 263 0.9637 _ 273 1.228 Y Point 1 is bhp from open -hole MDT Point is surface pressure measured by testers before 4 -point test. Poirot 3 is surface pressure from crystal pressure recorder. Point 4 is gauge pressure. Points 5, 6, and 7 is tree gauge pressure after long-term SI (4/1/05) Point 8 is tree gauge pressure after 28 hr SI 300 Point 9 is short -time shut in just before recompletion--not likely built up to static. Installation of booster compressor is assumed. Point 101s LT SIP w/ SPIDR C 200 O 100 o -- 0 200 400 600 800 1,000 1,200 Cumulative Production, MMcf 1,400 1,600 1,800 2,000 POINTNUMBER DATE BHP/Z, CUM PROD, LSMF (Automatic) (Optional) SITP, Psi. BHP, Psia Z Psia MMcf Include? (Y/h 1 9/22/2003 677 0.9086 745 0 n 2 11/20/2003 667 688 0.9072 759 0 y 3 2/11/2004 586 605 0.9179 659 106 y 4 6/18/2004 515 531 0.9275 573 310 y 5 12/31/2004 405 417 0.9427 443 666 n 6 4/30/2005 420 433 0.9406 460 680 n 7 7/16/2005 435 448 0.9385 478 682 Y 8 2/17/2006 325 335 0.9538 351 864 Y 9 9/12/2006 173 179 0.9752 183 1,068 n 10 5/21/2009 220 227 0.9686 234 1,228 0 11 9/2/2009 255 263 0.9637 _ 273 1.228 Y Point 1 is bhp from open -hole MDT Point is surface pressure measured by testers before 4 -point test. Poirot 3 is surface pressure from crystal pressure recorder. Point 4 is gauge pressure. Points 5, 6, and 7 is tree gauge pressure after long-term SI (4/1/05) Point 8 is tree gauge pressure after 28 hr SI Point 9 is short -time shut in just before recompletion--not likely built up to static. Installation of booster compressor is assumed. Point 101s LT SIP w/ SPIDR These results were prepared using Ryder Scott's Gas Material Balance. This jiLool Ryder Scott work product. --.._. - ..,......,,1 —.—\ —1.. 11 Kyner Scott Fe FIELD: NICOLAI CREEK Reservoir "= J COUNTY, STATE: KENAI PEN. BOR., (WEST SIDE OF COOK INLET). ALASKA Solutions 435 RESERVOIR: BELUGA (TSUGA 2.7 8 2-8) PERFS AT 1552-1904(Public) 505 —' ' Wlchert-Aziz correction for contaminants, if any (Protected) , WELLHEAD TEMP, °F: 40.0 SOUR GAS MOLE % Least Squares Mean Fit Results BOTTOMHOLE TEMP, °F: 74.0 N, 0.87 Y -Intercept, BHPIz 734 WET GAS GRAVITY: 0.562 CO, 0.33 OGIP, MMCF 572 TVD, FEET: 1,728 H2S 0.00 351 10 COND. CORR7 (Y/N): N EUR, MMCF 547 Corrected' Tc, "R: 343.56 Recovery Factor 0.9554 Corrected' Pc, Psia: 672.16 BHP/z 0 Abandonment 32 1,000 300 I (Optional) I SITP, Psia t= LSMF Data Excl. Data • EUR = 547 ♦ OGIP = 572 452 0.9414 300 9/26/2006 650 2 2/10/2007 435 3 5/1/2007 505 4 7/16/2007 475 700 8/11/2007 810 6 9/25/2003 0 n 7 8/11/2007 389 8 11/6/2007 385 9 5/29/2008 351 10 300 260 11 5/7/2009 215 r C 5/21/2009 220 /9 9/2/2009 255 Point 6 is original MDT data avg gradient from 1832' and 1438' Point 9 is SPIDR reading after 7 day SI 300 Point 10 is 2-3 day SITP O 100 O O ` t00 !00 00 0 0 100 200 300 400 Cumulative Production, MMcf POINT NUMBER I DATE _ (Automatic) I (Optional) I SITP, Psia 2 y 452 0.9414 1 9/26/2006 650 2 2/10/2007 435 3 5/1/2007 505 4 7/16/2007 475 5 8/11/2007 810 6 9/25/2003 0 n 7 8/11/2007 389 8 11/6/2007 385 9 5/29/2008 351 10 10/13/2008 260 11 5/7/2009 215 r C 5/21/2009 220 /9 9/2/2009 255 Point 6 is original MDT data avg gradient from 1832' and 1438' Point 9 is SPIDR reading after 7 day SI 274 Point 10 is 2-3 day SITP 'oint 1 is SITP of initial test BHP, Psia I Z 500 600 700 BHP/Z, I CUM PROD, I LSMF 676 0.9139 739 2 y 452 0.9414 480 94 n 525 0.9323 563 109 n 493 0.9362 527 159 y 637 0.9186 693 163 n 810 0.8981 902 0 n 404 0.9475 426 163 n 400 0.9480 422 208 n 365 0.9525 383 271 Y 270 0.9647 280 325 Y 223 0.9707 230 385 n 228 0.9701 235 385 n 265 0.9653 274 385 Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. Aurora Gas, LLC Nicolai Creek Unit No. 1-B Current Configuration (12116106) 2-7M" 65 0.1-55 tbg to surface 13 3/8" 540 J-55 Surface ('sg at 1,904'. Cmtd to surface w/ 1,530 sx "G". Carya 2-1.2 Peris: 2,307' - 2,326' MD 2,350'- 2,370' MD (TVD 2,254' -2,316') , R 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')' Drilled 26" Hole 20" 940 H-40 Conductor set at 232', Cmtd to surface w/300 sx "G". Drilled 17 12" Hole Sliding Sleeve w/ X -profile a,' 2,268' G-77 Packer (g) 2,280' (Closed) Sliding Sleeve w/ X -profile (a 2,375' G-77 Packer Qa 2,440' 19 %Z y1,9,5 Sliding Sleeve w/ X -profile n 2,742' G-77 Packer L 2,765' X -nipple (a) 2,775' Fairweather E&P Services, Inc. I Lone Creek No. 1 Rev. 1.0 1 7/312006 WJP I Drawing Not To Scale - VTA Packer @ 3,145' ' XN Nipple @ 3,184' (plugged) Carya 24.2 Perfs: 3,191 -3,211' MD r "J'3 Well completed with sand (TVD 3.137"- 3,157') exclusion screens across Carya 2-5.1 Perfs: . the indicated perforations. 3,371'-3,401' MID (TVD 3307'- 3,348') • r -• Cement Retainer C 3,500' Carya 2-6.1 Perfs- erfs:3.560'- 3,575' MD 3J60'- (TVD 3.506- -3.5211 Float collar a, 3,604' NID Float shoe w 3,648' MD 7" 230.1-55 Production TD a' 3.672' NID (3.61T TN'D) Csg (aD 3,650'NID (3 595' TVD). Cmtd to surface w/ 82 bbls "G" lead at 12.5 ppg and 67 bbls "G" tail at 15.8 ppg. Fairweather E&P Services, Inc. I Lone Creek No. 1 Rev. 1.0 1 7/312006 WJP I Drawing Not To Scale �NaCreek No. 2 Proposed Nicolai Creek Field Alaska Current Production 27/8" Production Tubing n i 36" Hole 30"@80mi I I !� i CMT'D to surface W/ 300 SX 26" Hole 20" 94# @ 286' CMT'Dto surface W/ 650 SX 17 1/2" Hole 13 3/8" 54.5# @ 1934' CM TD W/1600 SX 5" Meshrite Screen 9 7/8" Hole Original production perforations 4 112 SPF from 3270* to 3315' cemented over during 1991 Suspension Procedure 7" 26# @ 3585' MD CM TD W/1400 SX TD @ 5011' MD 4086' TVD I Attachment I 5 SPF @ 298' Squeezed w/ 200 sx in 1991 5 SPF @ 677' Squeezed wl 215 sx in 1991 ') TOC @-1900'MD in 13 3/8" X 7" annulus i 2.313" ID X -Nipple at 2288.8' Permanent Packer at 2327' Perforate @ 5 SPF 2426' - 2476' Perforate @ 5 SPF 2700' - 2716' Perforate @ 5 SPF 2893' to 2916' 87 Sk Class "G" Cement Plug 3102'- 3537' Plug (Baffle Plate) @ 3543' MD ORWMNOTTOSGLE NICOLAI CREEK No.2 F9IItWE9THERE&P Rev. 01 / DHV 05Se0-02 'WRVICFS,N0 NCU 9 ACTUAL WELLBORE CONFIGURATION After Recompletion of Sept. 2006 Upper Completion New Perfs @ 1148-1170' 1190-1200' 1218-1224' 1248-1254' 1258-1264' Middle Completion Existing Perfs 1320-1330' 1343-1393' 1407-1447' Lower Completion New Perfs @ 1552-1562' 1624-1629' 1641-1646' 1652-1662' 1689-1694' 1748-1758' 1768-1778' 1827-1837' 1894-1904' 2-7/8" 6.5# EUE Tubing Sliding Sleeve (Pkr Fluid) @ 104; Hydro I Hydraullic Set Packer @ 1090" Production Sliding Sleeve at 1130' Blast Joints Across Perfs, at 1149-1170', 1188-1228', & 1246-1267' Production Sliding Sleeve at 1271' Seal Bore Packer @ 1284' (Retrievable) Production Sliding Sleeve 1483'w/2.31"X HydroI Packer @ 1496' Prod Sliding Sleeve @1796' Hydro I Packer at 1807' XN Nipple @ 1815'w/ 2.312" bor Screens at 1828-38' & 1894-1904 PBTD - 2102' date 11/15/2003 12/15/2003 1/1512004 2/15/2004 3/15/2004 4/15/2004 5/15/2004 6/1512004 7/15/2004 8/15/2004 9/15/2004 10/15/2004 11/1512004 12/16/2004 1/16/2005 2/15/2005 3/15/2005 4/15/2005 5/15/2005 6/1512005 7/15/2005 8115/2005 9/1512005 10/15/2005 11/1512005 12/15/2005 1/15/2006 2/15/2006 3/15/2006 4/14/2006 5/14/2006 6/14/2006 7/14/2006 8/14/2006 9/13/2006 10/13/2006 11113/2006 12/13/2006 1/15/2007 2/15/2007 3/15/2007 4/15/2007 5/1512007 6/1511007 7/15/2007 8/15/2007 9/15/2007 10/15/2007 11/1511007 12/15/2007 1/15/2008 2/15/2008 3/15/2008 4/15/2008 5/15/2008 6/1512008 7/16/2008 8/15/2008 9/15/2008 10/15/2008 11/15/2008 12/1512008 1/15/2009 2/15/2009 3/15/2009 4/1612009 5/15/2009 6/15/2009 7/1512009 8/15/2009 oil gas water 34859 Injection wells 58875 Days On 0 1099 52 0 1 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 875 0 0 1 5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 181 1 5466 7 0 34859 28 0 58875 47 0 43158 16 0 31058 20 0 13963 15 0 133 0 0 22452 32 0 21637 40 0 2186 20 0 7248 13 0 7977 10 0 4621 10 0 7153 10 0 3727 3 0 3466 2 0 0 0 0 0 0 0 0 0 0 0 0 0 12405 9 0 2931 7 0 954 7 0 3858 7 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 0 AURORA GAS CUMLTV 290282 355 MCF BW MCFPD TPress 550 979 side tracked and Completed 0 1490 0 1490 0 1490 175 1400 producing sand 0 1400 0 1400 0 1400 0 1400 0 1080 0 1440 0 1446 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 0 1440 181 1440 0 1440 0 1440 recompletionIPB 0 1300 Rewinpletion—add upper perls 0 1400 0 1300 0 1260 260 280 1585 840 open upper sleeves 1899 460 1598 310 1002 270 997 270 133 500 SRP 936 230 746 180 547 160 360 SITP 1035 160 614 160 660 350 SIP 650 280 466 275 495 280 Low market demand 300 SIP 320 SIP 320 SIP 320 SIP 517 110 163 80 119 280 SIP 429 270 SIP 0 270 SIP 0 300 SIP 0 300 sip 0 300 SIP 0 305 0 300 SIP 0 313 SIP 0 313 SIP 0 313 SIP 0 313 SIP AURORA GAS NICOLAI CREEK UNIT I date Ni gas water Cum Prod wells 12/15/1959 0 a 0 0 1115/1970 0 0 0 0 61152003 0 0 0 0 7/1512003 0 0 0 0 8/152003 0 0 0 0 9/152603 0 0 0 0 101/5/2003 0 a 0 0 11/15/2003 0 1914 0 1914 12/15/2003 0 78355 0 80269 1/15/2004 0 61680 0 141929 2/I5/2004 0 2840 0 1"769 3/152004 0 19304 0 184073 411520D4 0 25135 0 189208 5/152004 a 77632 0 2660,10 6/152004 0 15493 0 282333 7/152004 0 39588 2 321919 8/1512004 0 45740 1 367659 9/15/2004 0 33862 1 401521 10/162004 0 27067 1 428588 111152004 0 19507 1 "8095 12115/20D4 0 13221 1 461316 1/152005 0 0 0 461316 2/15/2005 0 0 0 461316 3/15/2005 0 6 0 461322 4152005 0 10564 0 471886 5/15/2035 0 0 0 471886 6/152005 0 0 0 471886 7/152005 0 2620 0 474506 8/152005 0 0 0 474506 9/1512005 a 0 0 474506 1111152005 0 498 a 475004 11/152005 0 27836 0 502840 127/52035 0 26588 4 529428 1/15/1006 0 18629 1 548057 271520118 0 12073 0 560130 31152006 0 11846 1 571976 4/152006 0 9635 0 W1611 5/152006 0 8464 1 59W75 6/15200(3 0 6296 0 596371 7/152006 0 6344 0 602715 WISr 008 0 6033 0 608746 91152006 0 0 0 W5748 10/162606 0 2694 0 611442 IMMIX) 0 11445 0 622887 12/15/2006 0 849 0 623736 1/15/2007 0 a 0 623736 2/152007 0 0 0 623736 3I152007 a 5978 0 629714 41152607 0 1963 0 631677 5/15/2007 0 7649 0 639326 6/15/2007 0 4979 0 644305 7/t52W7 0 632 0 645137 8/1512007 0 11310 0 658117 9/152"7 0 10520 0 666967 10/152607 0 10273 0 677240 11/1512007 0 6668 0 663908 72J152W7 0 5653 0 689561 1/152008 0 3063 0 592624 2/152006 0 2395 0 695019 3/15/2008 0 8283 0 703302 4/15/2008 D 4718 1 708020 5/15/2006 0 3706 1 711728 6/15/2008 0 5038 2 716764 7/152608 0 1361 2 718125 6HSQ" 0 5286 1 723411 91152008 0 3426 1 726837 1011520DO 0 2356 1 729193 11/15/2008 0 10 0 729203 12/1512008 a 0 0 728203 11752060 0 0 0 729203 2/75/2009 0 3631 1 732834 3/152009 0 4645 1 737479 4/142060 0 1152 0 738631 5/15/2009 0 0 0 738631 6/1513009 0 0 0 738631 7/152009 0 0 0 738631 8/15/2009 0 0 0 738631 Days On ✓]MCFPD T Press 0 0 RE-ENTERED AND 0 RECOMPLETED WELL 0 0 0 0 1 1 1914 1 19 4124 1 15 4111 1 1 2840 1 7 2758 1 10 2514 1 31 2504 1 7 2213 1 17 2329 1 28 1634 1 30 1129 1 31 873 1 23 848 1 18 735 0 0 0 0 0 0 0 1 6 1 9 1174 0 0 0 0 0 0 1 3 873 0 0 0 0 0 0 1 0 0 1 28 994 1 31 858 1 31 601 1 26 464 1 30 395 1 W 321 1 31 273 1 30 210 1 31 205 1 26.3 229 0 0- 1 5 539 1 25 4% 1 13 65 1 0 0 0 0 1 23 260 1 5 393 1 20 382 1 12 415 1 2 416 1 26 435 1 23 457 1 26 395 1 21 318 1 26 217 1 19 161 1 9 266 1 14 592 1 16 295 1 17 218 1 29 174 1 6 227 1 31 171 1 21 183 1 25 94 1 1 10 a 1 0 0 1 0 1 28 130 1 31 150 1 10 115 1 0 0 1 0 0 1 0 0 1 0 0 AURORA CUMMLTV 738,631 25 MCF BW AURORA GAS NICOLAI CREEK UNIT i2 775 M—' — l Z 700 650 755 780 680 500 580 410 340 300 260 280 300 340 SI for commercial reasons 340 370 285 390 390 340 400 400 420 350 new conbacl, "her poces 240 200 160 150 130 120 120 110 130 160 260 160 225 255 275 260 260 240 260 260 210 165 160 160 W 110 160 SIP 20 Install booster compressor 105 SIP 115 2 75 1 1 125 SIP Move booster to NCU 3 175 SIP 210 SIP 240 SIP 155 135 195 SIP 228 SIP 260 SIP 260 SIP 285 SIP date oil gas water wells Days On MCFPD T Press 11/152003 0 793 0 1 0 0 Middle Completion 12/152003 0 68189 0 1 18 3788 550 1/152004 0 38620 0 1 15 2575 550 2/152004 0 573 0 1 1 573 590 3/15/2004 0 31840 0 1 13 2449 560 4/152004 0 59576 0 1 22 2708 540 �l j 5/152004 0 79158 0 1 37 2553 520 6/152004 0 53103 0 1 19 2795 520 7/152004 0 36134 4 1 16 2258 460 8/152004 0 72869 1 1 28 2602 440 9/15/2004 0 76400 1 1 30 2547 380 10/752004 0 68267 1 1 31 2202 340 111152004 0 48475 1 1 29 1672 360 12/152D04 0 31880 1 1 18 1771 360 1/15/2005 0 508 0 1 1 508 360 SI for commercial reasons 2/152005 0 112 0 1 1 112 360 3/15/2005 0 24 0 1 1 24 390 4/152005 0 13527 0 1 9 1503 380 5/152005 0 0 0 0 0 0 405 6/162005 0 0 0 0 0 0 4D5 7/152005 0 2361 0 1 3 787 410 8/152005 0 0 0 0 0 0 420 9/152005 0 0 0 0 0 0 420 10/152005 0 932 0 1 1 932 420 11/152005 0 46415 0 1 28 1658 280 new contract, higher price 12/152005 0 55650 0 1 31 1795 330 1/152006 0 53814 2 1 30 1794 280 2/15/2006 0 43877 0 1 26 1688 200 3/15/2006 0 42677 1 1 30 1423 160 4/1512005 0 37736 0 1 30 1258 150 5/15/2005 0 34293 0 1 31 1106 135 8/15/2005 0 25269 2 1 30 842 135 7/15/2005 0 21801 1 1 31 703 135 8/15/2006 0 17040 0 1 31 550 150 9/15/2006 0 8763 1 11 797 140 10/15/2006 0 2944 1 3.5 841 490 re completion 17/152006 0 23015 7 1 30 767 350 Only Lower Completion Open 12/752006 0 26879 1 1 30 896 400 1/152007 0 21350 1 1 30 712 350 2/15/2007 0 16378 1 1 27 607 280 3/15/2007 0 18087 1 1 31 583 255 4/152007 0 2677 1 1 5 535 255 5/15/2007 0 26870 2 1 31 867 190 6/152007 0 8656 0 1 12 722 440 SIP 7/152007 0 10310 0 1 13 793 230 8/152007 0 20116 1 1 27 745 170 91152007 0 15670 1 1 23 681 370 SITP 10/152007 0 14881 1 1 23 647 350 SRP 11/15/2007 0 15203 1 1 23 661 350 SIP 12/152007 0 12085 1 1 21 575 90 1/15/2008 0 10887 1 1 19 573 110 2/15/2008 0 4161 1 1 19 219 110 3/15/2008 0 3957 1 0 12 330 300 SIP AIM 62008 0 8299 6 1 16 519 350 SIP 51152008 0 9627 30 1 17 566 350 SIP 6/152008 0 14971 3 1 29 516 350 SIP 7/152/)08 0 8374 1 1 21 399 125 81152008 0 10626 1 1 31 343 82 9/152006 0 9104 1 1 23 396 80 10/152006 0 11017 1 1 27 408 290 Open middle zone to commingle on 10/28/08 11/75/2008 0 28287 9 1 30 943 270 12/15/2008 0 60732 0 1 31 1959 220 1/152009 0 46379 2 1 30 1546 185 2/15/2009 0 41404 20 1 28 1479 160 3/152009 0 39597 0 1 31 1277 140 4/1512009 0 15395 0 1 16 962 185 5/152009 0 0 0 1 0 0 205 SIP 6/152009 0 0 0 1 0 0 225 7/152009 0 0 0 1 0 0 225 8/15/2009 0 0 0 1 0 0 240 NCO 9 CUM 711 Lower C= 326154 mcf 1,628,624 MCF BW NICOLAI CREEK FIELD SOUTH UNDESIGNATED & BELUGA POOLS 1 Aurora Gas, LLC N NCU-9 TSUGA GAS EXTENT -80 ACRES DATUM -1706' TVDSS INITIAL - 666 psig 5/2008 - 349 psig I SEC 30 I I SEC 29 I DATUM -2285' TVDSS i I DATUM -2285' TVDSS INITIAL - 1041 psig '- --- INITIAL - 1025 psig 5/2008 - 329 psig y` - 134¢ 5/2008 - 115 psig i ; (5/2009- 240 psig) 3 I Coastline DATUM -2537' TVDSS i CU 1A 228 INITIAL — 1211 psig j 5/2008 — 331 psig ` _—'-- --- NCU 7YONEK PA NCU 1 , N 2 „ 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