EXHIBIT 99.1

COOK INLET ENERGY

ESTIMATED FUTURE RESERVES

AND INCOME

AS OF APRIL 30, 2012

SEC PARAMETERS

EXECUTIVE SUMMARY

RALPH E. DAVIS ASSOCIATES, INC.

HOUSTON, TEXAS

RALPH E. DAVIS

ASSOCIATES, INC

June 12, 2012

Page 3

Cook Inlet Energy

June 12, 2012

Cook Inlet Energy

601 W. 5^th Ave, Suite 310

Anchorage, Alaska 99501

Gentlemen,

At the request of Miller Energy Resources, Inc. (“Miller”), your parent company, in connection with Miller’s Annual Report to its shareholders, the firm of Ralph E. Davis Associates, Inc (“Davis”) of Houston, Texas USA has prepared an estimate of the oil and natural gas reserves on specific leaseholds in which Cook Inlet Energy (CIE) has interest for CIE and Miller. This report presents our estimate of the proved developed producing, proved developed non-producing and proved undeveloped reserves anticipated to be produced from those leaseholds and remaining as of April 30, 2012. The subject properties are located in the State of Alaska, USA. This report was completed on June 12, 2012.

Davis has reviewed 100% of CIE’s proved properties located in Alaska. It is our opinion that these properties represent all of CIE’s oil and gas assets that may be classified as proved as per the Securities Exchange Commission directives as detailed later in this report.

The reserves associated with this review have been classified in accordance with the definitions of the Securities and Exchange Commission as found in Part 210—Form and Content of and Requirements for Financial Statements, Securities Act of 1933, Securities Exchange Act of 1934, Public Utility Holding Company Act of 1935, Investment Company Act of 1940, Investment Advisers Act of 1940, and Energy Policy and Conservation Act of 1975, under Rules of General Application § 210.4-10   Financial accounting and reporting for oil and gas producing activities pursuant to the Federal securities laws and the Energy Policy and Conservation Act of 1975. A summation of these definitions is included as a portion of this letter.

We have also estimated the future net revenue and discounted present value associated with these reserves as of April 30, 2012, utilizing a scenario of non-escalated product prices as well as non-escalated costs of operations, i.e., prices and costs were not escalated above current values as detailed later in this report. The present value is presented for your information and should not be construed as an estimate of the fair market value.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

RALPH E. DAVIS

ASSOCIATES, INC

June 12, 2012

Page 4

Cook Inlet Energy

The results of our study are summarized as follows:

Estimated Net Reserves and Income Data

Certain Leasehold Interests of

Cook Inlet Energy

As of April 30, 2012

	PROVED
	PRODUCING		NON-PRODUCING		UNDEVELOPED		TOTAL
Net Reserves
Oil/Condensate-MBbls	1,644		590		6,209		8,443
Gas-MMCF	204		2,125		1,956		4,286
Income Data (M$)
Future Gross Revenue	$	169,571	$	73,212	$	642,616	$	885,399
Ad Valorem and Other Taxes	$	3,645	$	1,575	$	13,813	$	19,032
Severance Taxes	$	841	$	298	$	3,151	$	4,291
Operating Costs	$	83,192	$	12,564	$	36,412	$	132,168
Capital Costs	$	—	$	18,242	$	57,090	$	75,332
Future Net Income (FNI)	$	81,894	$	40,532	$	532,151	$	654,577
FNI @ 10%	$	59,224	$	22,916	$	364,586	$	446,726

Note: There are differences in the addition as a result of computer program rounding of numbers.

Crude oil volumes are expressed in standard 42 gallon barrels. Gas volumes are expressed in million cubic feet (MMCF) at the official temperature of 60 degrees Farenheit and pressure base of 14.73 psia.

DATA SOURCE

Basic well and field data used in the preparation of this report were furnished by CIE. Records as they pertain to factual matters such as acreage controlled, the number and depths of wells, reservoir pressure and production history, the existence of contractual obligations to others and similar matters were accepted as presented.

Additionally, the analyses of these properties utilized not only the basic data on the subject wells but also data on analogous properties if needed. Well logs, ownership interest, revenues received from the sale of products and operating costs were furnished by CIE. No physical inspection of the properties was made nor any well tests conducted.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

RALPH E. DAVIS

ASSOCIATES, INC

June 12, 2012

Page 5

Cook Inlet Energy

Operating cost data for the previous twelve month period for which data was available were provided by CIE along with an average of each property’s lease operating expense and well operating expense for the same time period. This data was used to determine the direct cost of operation for each property or producing unit. In the case of properties that are currently not producing, CIE’s 2012 budget for that property or estimates made by CIE were used.

RESERVE ESTIMATES

The reserves presented in this report have been estimated using engineering and geological methods widely accepted in the industry. For the proved developed producing, the estimates were made when considered to be definitive, using performance methods that utilize extrapolations of various historical data including, but not limited to, oil, gas and water production and pressure history. For the other proved producing, proved behind pipe reserves and proved undeveloped reserves estimates were made using volumetric methods.

The accuracy of reserve estimates is dependent upon the quality of available data and upon the independent geological and engineering interpretation of that data. The quantities presented herein are estimated reserves of oil that geologic and engineering data demonstrate can be recovered from known reservoirs under current economic conditions with reasonable certainty. The reserves are calculated using acceptable methods and procedures and are believed to be reasonable; however, future reservoir performance may justify revision of these estimates.

PRICING PROVISIONS

The unit price used throughout this report for crude oil, condensate and natural gas is based upon the appropriate price in effect the first trading day of each month from May 1, 2011 through April 1, 2012 and averaged for the year.

Crude Oil - The unit price used throughout this report for crude oil is based upon the average of prices for the above indicated period using Alaska North Slope (ANS) pricing. An average crude oil price of $114.24 per barrel was held constant throughout the contract life of the property. Prices for liquid reserves scheduled for initial production at some future date were estimated using current prices on the same properties.

Adjustments were made to this price as follows:

1. Plus $0.995 for non-Redoubt crude.

2. Minus $0.45 for Redoubt crude.

3. Minus the ANS discount of $4.00/bbl was used.

4. Minus a “CISPRI allowance” (a spill response coop) of $0.3335/bbl.

5. Minus a shipping charge of $2.0345/bbl.

6. Minus a pipeline tariff (CIPL tariff) of $6.17/bbl.

7. Minus the pipeline tariff (KPL tariff) of $0.059/bbl.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

RALPH E. DAVIS

ASSOCIATES, INC

June 12, 2012

Page 6

Cook Inlet Energy

Natural Gas - The unit price used throughout this report for natural gas is based upon the average of prices for the above indicated period. An average natural gas price of $3.677 per MMBTU was calculated then adjusted by the area differential calculated of $2.693 per MMBTU with a resultant area price of $6.37 per MMBTU. This price was held constant throughout the life of the property. Prices for gas reserves scheduled for initial production at some future date were estimated using current prices on the same properties

Costs – Drilling, operating and abandonment costs were supplied by CIE for each property and were held constant for this report. These costs are based upon Authorities for Expenditure for the actual project or are estimated based upon comparison to similar work within the same area.

FUTURE NET INCOME

Future net income is based upon gross income from future production, less direct operating expenses and taxes. Estimated future capital for development costs was also deducted from gross income at the time it will be expended. No allowance was made for depletion, depreciation, income taxes or administrative expense.

Direct lease operating expense includes direct cost of operations of each lease or an estimated value for future operations based upon analogous properties. Lease operating expense and/or capital costs for drilling and completion were held constant throughout the remaining contract life of the properties.

GENERAL

Cook Inlet Energy has provided access to all of its accounts, records, geological and engineering data, reports and other information as required for this investigation. The ownership interests, product classifications relating to prices and other factual data were accepted as furnished without verification.

No consideration was given in this report to potential environmental liabilities (except for a scheduled Performance Bond deposit required by the State of Alaska) which may exist, nor were any costs included for potential liability to restore and clean up damages, if any, caused by past operating practices.

You should be aware that state regulatory authorities could, in the future, change the allocation of reserves allowed to be produced from a particular well in any reservoir, thereby altering the material premise upon which our reserve estimate may be based.

We have used all methods and procedures as is considered necessary under the circumstances to prepare this report.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

RALPH E. DAVIS

ASSOCIATES, INC

June 12, 2012

Page 7

Cook Inlet Energy

If investments or business decisions are to be made in reliance on these estimates by anyone other than our client, such person with the approval of our client is invited to arrange a visit so that he can evaluate the assumptions made and the completeness and extent of the data available on which the estimates are made.

Neither Ralph E. Davis Associates, Inc. nor any of its employees have any interest in the subject properties and neither the employment to make this study nor the compensation is contingent on its estimates of reserves and future income for the subject properties.

Very truly yours,

RALPH E. DAVIS ASSOCIATES, INC.

L. B. Branum, P.E.

Vice President

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

CERTIFICATE OF QUALIFICATION

I, Lloyd B. Branum, of 1717 St. James Place, Suite 460, Houston, Texas 77056 hereby certify:

1. I am an employee of Ralph E. Davis Associates, Inc., that has prepared an estimate of the oil and gas reserves on specific leaseholds in which Cook Inlet Energy has certain interests. The effective date of this evaluation is April 30, 2012.

2. I am Licensed Professional Engineer by the State of Texas, P.E. License number 42019.

3. I attended the University of Missouri at Rolla, Rolla, Missouri and graduated with a Bachelor of Science Degree in Petroleum Engineering in 1970. I have thirty nine years of experience in the Petroleum Industry of which over thirty years experience are in the conduct of evaluation and engineering studies relating to both domestic U.S. oil and gas fields and international energy assets.

4. I have prepared reserve evaluation studies and reserve audits for public and private companies for the purpose of reserve certification filings in foreign countries, domestic regulatory filings, financial disclosures and corporate strategic planning. I personally supervised and participated in the evaluation of the Cook Inlet Energy properties that are the subject of this report.

5. I do not have, nor do I expect to receive, any direct or indirect interest in the securities of Cook Inlet Energy or any affiliated organizations.

6. A personal field inspection of the properties was not made, however, such an inspection was not considered necessary in view of the information available from information, records and the files of the operator of the properties.

SIGNED: June 12, 2012.

_________________________________

Lloyd B. Branum, P.E.

Vice President

Ralph E. Davis Associates, Inc.

Securities and Exchange Commission        Page #PageNum#

§ 210.4-10   Definitions (of Reserves)

Modified, Effective 2009 for Filings of 12/31/2009 and Thereafter

SECURITIES AND EXCHANGE COMMISSION

DEFINITIONS OF RESERVES

The following information is taken from the United States Securities and Exchange Commission:

PART 210—FORM AND CONTENT OF AND REQUIREMENTS FOR FINANCIAL STATEMENTS, SECURITIES ACT OF 1933, SECURITIES EXCHANGE ACT OF 1934, PUBLIC UTILITY HOLDING COMPANY ACT OF 1935, INVESTMENT COMPANY ACT OF 1940, INVESTMENT ADVISERS ACT OF 1940, AND ENERGY POLICY AND CONSERVATION ACT OF 1975

Rules of General Application

§ 210.4-10   Financial accounting and reporting for oil and gas producing activities pursuant to the Federal securities laws and the Energy Policy and Conservation Act of 1975.

Reserves

Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.

Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).

Proved Oil and Gas Reserves

Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(i) The area of the reservoir considered as proved includes:

(A) The area identified by drilling and limited by fluid contacts, if any, and

(B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

(iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when:

(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and

(B) The project has been approved for development by all necessary parties and entities, including governmental

Note: There are differences in the addition as a result of computer program rounding of numbers.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

Securities and Exchange Commission        Page #PageNum#

§ 210.4-10   Definitions (of Reserves)

Modified, Effective 2009 for Filings of 12/31/2009 and Thereafter

entities.

(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

Reasonable certainty. If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate. A high degree of confidence exists if the quantity is much more likely to be achieved than not, and, as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease.

Reliable technology. Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation.

Probable Reserves

Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.

(i) When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates.

(ii) Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir.

(iii) Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves.

Possible Reserves

Possible reserves are those additional reserves that are less certain to be recovered than probable reserves.

(i) When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates.

(ii) Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project.

(iii) Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves.

(iv) The proved plus probable and proved plus probable plus possible reserves estimates must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar projects.

(v) Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the

Note: There are differences in the addition as a result of computer program rounding of numbers.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

Securities and Exchange Commission        Page #PageNum#

§ 210.4-10   Definitions (of Reserves)

Modified, Effective 2009 for Filings of 12/31/2009 and Thereafter

proved reservoir.

(vi) Pursuant to paragraph (a)(22)(iii) of this section, where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations.

Developed Oil and Gas Reserves

Developed oil and gas reserves are reserves of any category that can be expected to be recovered:

(i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

Undeveloped Oil and Gas Reserves

Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time.

(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty.

Additional Definitions:

Deterministic Estimate

The method of estimating reserves or resources is called deterministic when a single value for each parameter (from the geoscience, engineering, or economic data) in the reserves calculation is used in the reserves estimation procedure.

Probabilistic Estimate

The method of estimation of reserves or resources is called probabilistic when the full range of values that could reasonably occur for each unknown parameter (from the geoscience and engineering data) is used to generate a full range of possible outcomes and their associated probabilities of occurrence.

Reasonable Certainty

If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate. A high degree of confidence exists if the quantity is much more likely to be achieved than not, and, as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease.

Note: There are differences in the addition as a result of computer program rounding of numbers.

RALPH E. DAVIS ASSOCIATES, INC.

Texas Registered Engineering Firm F-1529

ONELINE

V 10 VALUE

					RESERVE	LIFE	GROSS	GROSS	NET	NET	NET	SEV	ADVAL	OP	CAPITAL	CASH		DISC
FIELD	LEASE	RESERVOIR	OPERATOR	MAJOR	CATEGORY	INDEX	OIL	GAS	OIL	GAS	SALES	TAX	TAX	COST	COST	FLOW		@10%
						(YRS)	(MBBLS)	(MMCF)	(MBBLS)	(MMCF)	(M$)	(M$)	(M$)	(M$)	(M$)	(M$)		(M$)
WEST MCARTHUR RIVER	WMRU 6	HEMLOCK-SEG B	COOK INLET	OIL	PROVED PRODUCING	11.7	894.8	-	716.4	-	73,526.1	367.6	1,580.2	1,881.6	-	69,696.7		46,464.3
WEST MCARTHUR RIVER	WMRU 5	HEMLOCK-SEG B	COOK INLET	OIL	PROVED PRODUCING	11.7	730.5	-	582.4	-	59,772.1	298.9	1,284.6	1,881.6	-	56,307		39,170.3
REDOUBT SHOAL	REDOUBT 07	HEMLOCK	COOK INLET	OIL	PROVED PRODUCING	11.2	366.8	-	310.1	-	31,384.7	156.9	674.5	2,380.9	-	28,172.4		20,464.9
WEST MCARTHUR RIVER	WMRU 1A	HEMLOCK-SEG A	COOK INLET	OIL	PROVED PRODUCING	7.4	44.1	-	34.9	-	3,586.5	17.9	77.1	1,196.2	-	2,295.4		1,769.7
WEST FORELAND	WF 2 LONG STRING	WF#2-9200` SAND	COOK INLET	GAS	PROVED PRODUCING	2.3	-	149.5	-	118.3	753.5	-	16.3	560.0	-	177.2		165.2
THREE MILE CREEK	THREE MILE CREEK 2	BELUGA/TYONEK	AURORA GAS LLC	GAS	PROVED PRODUCING	4.8	-	172.7	-	44.3	282.3	-	6.1	104.4	-	171.8		151.7
WEST FORELAND	WF 2 SHORT STRING	WF#2-8500` SAND	COOK INLET	GAS	PROVED PRODUCING	1.9	-	34.7	-	28.2	179.9	-	3.9	115.0	-	61.0		57.8
THREE MILE CREEK	THREE MILE CREEK 1	BELUGA/TYONEK	AURORA GAS LLC	GAS	PROVED PRODUCING	2.2	-	52.7	-	13.5	86.2	-	1.9	46.8	-	37.6		35.4
REDOUBT SHOAL	FIXED OPERATING COSTS	OSPREY PLATFORM	COOK INLET	OIL	PROVED PRODUCING	10.7	-	-	-	-	-	-	-	10,057.3	-	(10,057.3	)	(8,084.6	)
KUSTATAN FACILITY	KUSTATAN FACILITY EXPENSES		COOK INLET	OIL	PROVED PRODUCING	10.0	-	-	-	-	-	-	-	23,839.9	-	(23,839.9	)	(15,369.4	)
WEST MCARTHUR RIVER	FIXED OPERATING COSTS	HEMLOCK	COOK INLET	OIL	PROVED PRODUCING	10.7	-	-	-	-	-	-	-	41,128	-	(41,128	)	(25,601	)
					PROVED PRODUCING Total	84.5	2,036.3	409.7	1,643.8	204.4	169,571.3	841.3	3,644.6	83,191.7	-	81,893.7		59,224.2
REDOUBT SHOAL	REDOUBT 01	HEMLOCK	COOK INLET	OIL	PROVED NON-PRODUCING	16.2	700.0	-	589.7	-	59,672.6	298.4	1,282.5	3,731.3	1,560	52,800.4		33,865.4
REDOUBT SHOAL	REDOUBT 03	G-0 GAS SAND	COOK INLET	GAS	PROVED NON-PRODUCING	21.6	-	1,625	-	1,369.1	8,720.9	-	188.4	172.0	2,340	6,020.6		1,177.9
REDOUBT SHOAL	REDOUBT 04	LOWER TYONEK GAS ZONE	COOK INLET	GAS	PROVED NON-PRODUCING	19.7	-	700.0	-	592.5	3,774.5	-	81.5	505.1	1,622	1,566		253.8
KUSTATAN	KUSTATAN FIELD #1	TYONEK	COOK INLET	GAS	PROVED NON-PRODUCING	4.4	-	188.3	-	163.8	1,043.6	-	22.5	156.0	720.0	145.1		48.0
REDOUBT SHOAL	FIXED OPERATING COSTS	OSPREY PLATFORM	COOK INLET	OIL	PROVED NON-PRODUCING	11.7	-	-	-	-	-	-	-	8,000	-	(8,000	)	(4,341.2	)
REDOUBT SHOAL	PERFORMANCE BOND	OSPREY PLATFORM	COOK INLET	OIL	PROVED NON-PRODUCING	11.7	-	-	-	-	-	-	-	-	12,000	(12,000	)	(8,087.7	)
					PROVED NON-PRODUCING Total	85.2	700.0	2,513.3	589.7	2,125.4	73,211.6	298.4	1,574.9	12,564.4	18,242	40,532		22,916.2
REDOUBT SHOAL	REDOUBT 04A-	HEMLOCK CENTRAL FB	COOK INLET	OIL	PROVED UNDEVELOPED	16.4	1,321.9	-	1,110	-	112,319.3	561.6	2,414	4,812.9	6,120	98,410.8		64,597
REDOUBT SHOAL	REDOUBT 02A	HEMLOCK SOUTH FB	COOK INLET	OIL	PROVED UNDEVELOPED	13.8	1,124.7	-	949.8	-	96,108.3	480.5	2,065.6	4,090.4	6,120	83,351.9		58,869.3
REDOUBT SHOAL	REDOUBT 05A	HEMLOCK SOUTH FB	COOK INLET	OIL	PROVED UNDEVELOPED	14.1	1,124.7	-	943.5	-	95,475.4	477.4	2,052	4,090.4	6,120	82,735.7		56,459.1
WEST MCARTHUR RIVER	WMRU 9	HEMLOCK-SEG B	COOK INLET	OIL	PROVED UNDEVELOPED	11.3	1,100	-	861.7	-	88,439.2	442.2	1,900.7	1,733.8	8,700	75,662.5		54,399.1
REDOUBT SHOAL	REDOUBT 03A	HEMLOCK SOUTH FB	COOK INLET	OIL	PROVED UNDEVELOPED	14.4	1,124.7	-	940.2	-	95,140.4	475.7	2,044.8	4,090.4	6,120	82,409.5		54,349.6
REDOUBT SHOAL	REDOUBT SOUTH STEPOUT 9	HEMLOCK SSO	COOK INLET	OIL	PROVED UNDEVELOPED	15.6	1,191	-	1,003.4	-	101,539.9	507.7	2,182.3	4,336.5	10,500	84,013.4		51,720
WEST MCARTHUR RIVER	WMRU 8	HEMLOCK-SEG C	COOK INLET	OIL	PROVED UNDEVELOPED	6.1	523.0	-	400.8	-	41,133.7	205.7	884.0	833.3	8,700	30,510.7		23,653.2
WEST FORELAND	WF-3	8500 SAND	COOK INLET	GAS	PROVED UNDEVELOPED	6.1	-	1,942.8	-	1,460.1	9,301	-	200.9	620.0	3,900	4,580.1		3,124.8
THREE MILE CREEK	THREE MILE CREEK 3	BELUGA/TYONEK	AURORA GAS LLC	GAS	PROVED UNDEVELOPED	6.2	-	1,486.1	-	381.4	2,429.3	-	52.5	104.4	810.0	1,462.4		1,123.8
RAPTOR	RAPTOR 1	TYONEK	COOK INLET	GAS	PROVED UNDEVELOPED	10.9	-	3,819	-	114.6	729.8	-	15.8	-	-	714.0		450.9
REDOUBT SHOAL	FIXED OPERATING COSTS	OSPREY PLATFORM	COOK INLET	OIL	PROVED UNDEVELOPED	15.7	-	-	-	-	-	-	-	11,700	-	(11,700	)	(4,161	)

RALPH E. DAVIS ASSOCIATES, INC.

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PROVED UNDEVELOPED Total	130.4	7,510.1	7,247.9	6,209.2	1,956.1	642,616.3	3,150.8	13,812.5	36,411.9	57,090	532,151.1	364,585.8
GRAND TOTAL	300.1	10,246.4	10,170.9	8,442.7	4,285.9	885,399.2	4,290.5	19,032	132,168	75,332	654,576.8	446,726.2

RALPH E. DAVIS ASSOCIATES, INC.

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