DeGolyer
and MacNaughton
 5001
Spring Valley Road
 Suite 800
East
 Dallas,
Texas 75244
 APPRAISAL
REPORT
 as
of
 DECEMBER
31, 2009
 on
 CERTAIN
PROPERTIES
 owned
by
 LINN
ENERGY LLC
 
 SEC
CASE
 DeGolyer
and MacNaughton
  TABLE of
CONTENTS
  PageFOREWORD
                  1Scope
      of Investigation
                  1Authority
                  2Source
      of Information
                  2DEFINITION
      of RESERVES
                  4ESTIMATION
      of RESERVES
                  10VALUATION
      of RESERVES
                  12SUMMARY
      and CONCLUSIONS
                  15CERTIFICATE
      of QUALIFICATION
 DeGolyer
and MacNaughton
 5001
Spring Valley Road
 Suite 800
East
 Dallas,
Texas 75244
 
 APPRAISAL
REPORT
 as
of
 DECEMBER
31, 2009
 on
 CERTAIN
PROPERTIES
 owned
by
 LINN
ENERGY LLC
 
 SEC
CASE
  FOREWORD
  Scope of
Investigation   This  report  presents
an  appraisal,  as  ofDecember 31, 2009,
of the extent and value of the proved crude oil, condensate, natural gas liquids
(NGL), and natural gas reserves of certain properties owned by Linn Energy LLC
(Linn). The reserves estimated in this report are located in Arkansas,
California, Illinois, Kansas, Louisiana, Oklahoma, and Texas and represent 99.7
percent of Linn’s proved reserves. The properties appraised are listed in detail
in the related DeGolyer and MacNaughton report entitled “Appraisal Report as of
December 31, 2009 on Certain Properties owned by Linn Energy
LLC.”
 
 Reserves
estimated in this report are expressed as gross and net reserves. Gross reserves
are defined as the total estimated petroleum to be produced from these
properties after December 31, 2009. Net reserves are defined as that portion of
the gross reserves attributable to the interests owned by Linn after deducting
royalties and interests owned by others.
 
 This
report also presents values that were estimated for proved reserves using
initial prices and costs provided by Linn. Prices, as required by the Securities
and Exchange Commission (SEC) are the average of the price at the beginning of
the previous 12 months. Oil and condensate prices are
 2
 DeGolyer
and MacNaughton
 related
to the WTI Cushing price of $61.05 per barrel. Natural gas prices are related to
the Henry Hub price of $3.87 per million British thermal units (MMBtu). No escalation has been
applied to prices and costs. A detailed explanation of the future price and cost
assumptions is included in the Valuation of Reserves section of
this report.
 
 Values of
proved reserves in this report are expressed in terms of estimated future gross
revenue, future net revenue, and present worth. Future gross revenue is that
revenue which will accrue to the appraised interests from the production and
sale of the estimated net reserves. Future net revenue is calculated by
deducting estimated production taxes, ad valorem taxes, operating expenses,
and capital costs from the future gross revenue. Operating expenses include
field operating expenses, transportation expenses, compression charges, and an
allocation of overhead that directly relates to production activities. Future
income tax expenses were not taken into account in the preparation of these
estimates. Present worth is defined as future net revenue discounted at a
specified arbitrary discount rate compounded monthly over the expected period of
realization. In this report, present worth values using a discount rate of 10
percent are reported.
 
 Estimates
of oil, condensate, natural gas liquids, gas reserves, and future net revenue
should be regarded only as estimates that may change as further production
history and additional information become available. Not only are such reserves
and revenue estimates based on that information which is currently available,
but such estimates are also subject to the uncertainties inherent in the
application of judgmental factors in interpreting such information.
 
 Authority   This
report was prepared at the request ofMr. Arden
L. Walker, Senior Vice President,
Linn.
 
 Source of
Information Data  used  in   the   preparation   of   thisreport were obtained from Linn, from records on file with the appropriate
regulatory agencies, and from public sources. In the preparation of this report
we have relied, without independent verification, upon information furnished by
Linn with respect to its property interests, production from
 3
 DeGolyer
and MacNaughton
 such
properties, current costs of operation and development, current prices for
production, agreements relating to current and future operations and sale of
production, and various other information and data that were accepted as
represented. A field examination of the properties was not considered necessary
for the purposes of this report.
 4
 DeGolyer
and MacNaughton
 DEFINITION of
RESERVES
  Petroleum
reserves included in this report are classified as proved. Only proved reserves
have been evaluated for this report. Reserves classifications used in this
report are in accordance with the reserves definitions of Rules 4–10(a) (1)–(32)
of Regulation S–X of the SEC. Reserves are judged to be economically producible
in future years from known reservoirs under existing economic and operating
conditions and assuming continuation of current regulatory practices using
conventional production methods and equipment. In the analyses of
production-decline curves, reserves were estimated only to the limit of economic
rates of production under existing economic and operating conditions using
prices and costs consistent with the effective date of this report, including
consideration of changes in existing prices provided only by contractual
arrangements but not including escalations based upon future conditions. The
petroleum reserves are classified as follows:
 
 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,
 5
 DeGolyer
and MacNaughton
 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 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.
 
 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.
 6
 DeGolyer
and MacNaughton
 (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.
 
 (iv) See
also guidelines in paragraphs (iv) and (vi) of the definition of possible
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
 7
 DeGolyer
and MacNaughton
 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 proved reservoir.
 
 (vi)
Pursuant to paragraph (iii) of the proved oil and gas definition, 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.
 8
 DeGolyer
and MacNaughton
 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 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 [section 210.4–10 (a) Definitions], or by other evidence using
reliable technology establishing reasonable certainty.
 
 The
extent to which probable and possible reserves ultimately may be reclassified as
proved reserves is dependent upon future
 9
 DeGolyer
and MacNaughton
 drilling,
testing, and well performance. The degree of risk to be applied in evaluating
probable and possible reserves is influenced by economic and technological
factors as well as the time element. No probable or possible reserves have been
evaluated for this report.
 10
 DeGolyer
and MacNaughton
 ESTIMATION of
RESERVES
  Estimates
of reserves were prepared by the use of geological and engineering methods
generally accepted by the petroleum industry. The method or combination of
methods used in the analysis of each reservoir was tempered by experience with
similar reservoirs, stage of development, quality and completeness of basic
data, and production history.
 
 When
applicable, the volumetric method was used to estimate the original oil in place
(OOIP) and original gas in place (OGIP). Structure maps were prepared to
delineate each reservoir, and isopach maps were constructed to estimate
reservoir volume. Electrical logs, radioactivity logs, core analyses, and other
available data were used to prepare these maps as well as to estimate
representative values for porosity and water saturation. When adequate data were
available and when circumstances justified, material-balance and other
engineering methods were used to estimate OOIP or OGIP.
 
 Estimates
of ultimate recovery were obtained after applying recovery factors to OOIP or
OGIP. These recovery factors were based on consideration of the type of energy
inherent in the reservoirs, analyses of the petroleum, the structural positions
of the properties, and the production histories. When applicable,
material-balance and other engineering methods were used to estimate recovery
factors. An analysis of reservoir performance, including production rate,
reservoir pressure, and gas-oil ratio behavior, was used in the estimation of
reserves.
 
 For
depletion-type reservoirs or those whose performance disclosed a reliable
decline in producing-rate trends or other diagnostic characteristics, reserves
were estimated by the application of appropriate decline curves or other
performance relationships. In the analyses of production-decline curves,
reserves were estimated only to the limits of economic production based on
current economic conditions.
 
 In
certain cases, when the previously named methods could not be used, reserves
were estimated by analogy with similar wells or reservoirs for which more
complete data were available.
 
 The gas
reserves included herein are reported as sales gas. Sales gas is defined as that
gas to be delivered into a gas
 11
 DeGolyer
and MacNaughton
 pipeline
for sale after separation, processing, fuel use, and flare. All gas quantities
are expressed at a temperature base of 60 degrees Fahrenheit (°F) and at the
legal pressure base of the state or area in which the reserves are located.
Condensate reserves estimated herein are those to be recovered by conventional
lease separation. Natural gas liquids reserves are estimated to be those
attributable to the leasehold interests appraised based on historical yield
information.
 
 In the
preparation of this report, as of December 31, 2009, gross production
estimated to December 31, 2009, was deducted from gross ultimate recovery to
arrive at the estimate of gross reserves. In some fields, this required that the
production rates be estimated for up to 4 months, since production data from
certain properties were available only through August 2009.
 
 The
following table presents estimates of the proved reserves, as of December 31,
2009, of the properties appraised, expressed in thousands of barrels (Mbbl) or
millions of cubic feet (MMcf):
 
 Gross
      Reserves
              
              Net
      ReservesOil
      and
                Condensate
                (Mbbl)
              
              Wet
                Gas
                (MMcf)
              
              Oil
      and
                Condensate
                (Mbbl)
              
              NGL
                (Mbbl)
              
              Sales
                Gas
                (MMcf)Developed
      Producing
              
              
              159,780
              
              
              
              1,534,748
              
              
              
              72,778
              
              
              
              32,367
              
              
              
              515,674Developed
      Nonproducing
              
              
              9,401
              
              
              
              112,900
              
              
              
              5,044
              
              
              
              1,461
              
              
              
              29,397Undeveloped
              
              
              34,360
              
              
              
              532,755
              
              
              
              24,252
              
              
              
              20,264
              
              
              
              225,261Total
      Proved
              
              
              203,541
              
              
              
              2,180,403
              
              
              
              102,074
              
              
              
              54,092
              
              
              
              770,332
  12
 DeGolyer
and MacNaughton
 VALUATION of
RESERVES
  Revenue
values in this report were estimated using the initial prices and costs provided
by Linn. Future prices were estimated using guidelines established by the SEC
and the Financial Accounting Standards Board (FASB).
 
 In this
report, values for proved reserves were based on projections of estimated future
production and revenue prepared for these properties.
 
 The
following assumptions were used for estimating future prices and
costs:
  Oil
and Condensate Prices
  Oil and
condensate prices were calculated using specified differentials for each lease
to a price of $61.05 per barrel. No escalation was applied to the prices. The
WTI Cushing price of $61.05 per barrel is the 12-month average price, calculated
as the unweighted arithmetic average of the first-day-of-the-month price for
each month within the 12-month period prior to the end of the reporting period.
The weighted average price for the proved reserves over the lives of the
properties was $56.93 per barrel.
  NGL
Prices
  NGL
prices were calculated using specified differentials for each lease to a price
of $61.05 per barrel. No escalation was applied to the prices. The WTI Cushing
price of $61.05 per barrel is the 12-month average price, calculated as the
unweighted arithmetic average of the first-day-of-the-month price for each month
within the 12-month period prior to the end of the reporting period. The
weighted average price for the proved reserves over the lives of the properties
was $32.97 per barrel.
 13
 DeGolyer
and MacNaughton
 Natural
Gas Prices
  Natural
gas prices were calculated using specified differentials and British thermal
unit (Btu) factors for each lease supplied by Linn to a Henry Hub price of $3.87
per million Btu. No escalation was applied to the prices. The Henry Hub gas
price of $3.225 per thousand cubic feet is the 12-month average price,
calculated as the unweighted arithmetic average of the first-day-of-the-month
price for each month within the 12-month period prior December 31, 2009. The
weighted average price for the proved reserves over the lives of the properties
was $3.225 per thousand cubic feet.
  Operating
Expenses and Capital Costs
  Current
operating expenses and capital costs, based on information provided by Linn,
were used in estimating future costs required to operate the properties. In
certain cases, future costs, either higher or lower than current costs, may have
been used because of anticipated changes in operating conditions. These costs
were not escalated for inflation.
 
 The
future revenue to be derived from the production and sale of the proved
reserves, as of December 31, 2009, of the properties appraised is estimated as
follows:
 
 ProvedDeveloped
                Producing
                (M$)
              
              Developed
                Nonproducing
                (M$)
              
              Undeveloped
                (M$)
              
              Total
                Proved
                (M$)Future
      Gross Revenue
              
              
              6,794,997
              
              
              
              428,943
              
              
              
              2,855,475
              
              
              
              10,079,415Production
      and Ad Valorem Taxes
              
              
              531,434
              
              
              
              34,334
              
              
              
              242,600
              
              
              
              808,368Operating
      Expenses
              
              
              2,599,681
              
              
              
              86,293
              
              
              
              703,715
              
              
              
              3,389,689Net
      Other Expenses
              
              
              2,483
              
              
              
              0
              
              
              
              0
              
              
              
              2,483Capital
      Costs
              
              
              8,707
              
              
              
              29,849
              
              
              
              788,790
              
              
              
              827,346Salvage
      & Abandonment
              
              
              (9,022
              )
              
              
              (665
              )
              
              
              (1,081
              )
              
              
              (10,768
              )Future
      Net Revenue*
              
              
              3,661,714
              
              
              
              279,132
              
              
              
              1,121,451
              
              
              
              5,062,297Present
      Worth at 10 Percent*
              
              
              1,375,429
              
              
              
              96,735
              
              
              
              242,467
              
              
              
              1,714,631*
      Future income taxes have not been taken into account in the preparation of
      these estimates.
  14
 DeGolyer
and MacNaughton
 Timing of
capital expenditures and the resulting development of production were based on a
development plan provided by Linn.
 
 In our
opinion, the information relating to estimated proved reserves of oil,
condensate, NGL, and natural gas, estimated future net revenue from those proved
reserves, and present worth of estimated future net revenue from proved reserves
of oil, condensate, natural gas liquids, and gas contained in this report has
been prepared in accordance with Paragraphs 932-235-50-4, 932-235-50-6,
932-235-50-7, 932-235-50-9, 932-235-50-30, and 932-235-50-31(a), (b), and (e) of
the Accounting Standards Update 932-235-50, Extractive Industries – Oil and Gas
(Topic 932): Oil and Gas Reserve Estimation and Disclosures (January
2010) of the Financial Accounting Standards Board and Rules 4–10(a) (1)–(32) of
Regulation S–X and Rules 302(b), 1201, 1202(a) (1), (2), (3), (4), (8), and
1203(a) of Regulation S–K of the Securities and Exchange Commission; provided,
however, future income tax expenses have not been taken into account in
estimating the future net revenue and present worth values set forth
herein.
 
 To the
extent that the above-enumerated rules, regulations, and statements require
determinations of an accounting or legal nature or information beyond the scope
of our report, we are necessarily unable to express an opinion as to whether the
above-described information is in accordance therewith or sufficient
therefor.
 15
 DeGolyer
and MacNaughton
 SUMMARY and
CONCLUSIONS
  Linn owns
working and royalty interests in certain properties located in Arkansas,
California, Illinois, Kansas, Louisiana, Oklahoma, and Texas. The estimated net
proved reserves of the properties appraised, as of December 31, 2009, are
summarized as follows, expressed in thousands of barrels (Mbbl) or millions of
cubic feet (MMcf):
 
 Net
      ReservesOil
      and
                Condensate
                (Mbbl)
              
              NGL
                (Mbbl)
              
              Sales
                Gas
                (MMcf)Developed
      Producing
              
              
              72,778
              
              
              
              32,367
              
              
              
              515,674Developed
      Nonproducing
              
              
              5,044
              
              
              
              1,461
              
              
              
              29,397Undeveloped
              
              
              24,252
              
              
              
              20,264
              
              
              
              225,261Total
      Proved
              
              
              102,074
              
              
              
              54,092
              
              
              
              770,332
 
 The
estimated revenue and expenditures attributable to Linn’s interests in the
proved reserves, as of December 31, 2009, of the properties appraised under the
aforementioned assumptions concerning future prices and costs are summarized as
follows:
 
 ProvedDeveloped
                Producing
                (M$)
              
              Developed
                Nonproducing
                (M$)
              
              Undeveloped
                (M$)
              
              Total
                Proved
                (M$)Future
      Gross Revenue
              
              
              6,794,997
              
              
              
              428,943
              
              
              
              2,855,475
              
              
              
              10,079,415Production
      and Ad Valorem Taxes
              
              
              531,434
              
              
              
              34,334
              
              
              
              242,600
              
              
              
              808,368Operating
      Expenses
              
              
              2,599,681
              
              
              
              86,293
              
              
              
              703,715
              
              
              
              3,389,689Net
      Other Expenses
              
              
              2,483
              
              
              
              0
              
              
              
              0
              
              
              
              2,483Capital
      Costs
              
              
              8,707
              
              
              
              29,849
              
              
              
              788,790
              
              
              
              827,346Salvage
      & Abandonment
              
              
              (9,022
              )
              
              
              (665
              )
              
              
              (1,081
              )
              
              
              (10,768
              )Future
      Net Revenue*
              
              
              3,661,714
              
              
              
              279,132
              
              
              
              1,121,451
              
              
              
              5,062,297Present
      Worth at 10 Percent*
              
              
              1,375,429
              
              
              
              96,735
              
              
              
              242,467
              
              
              
              1,714,631*
      Future income taxes have not been taken into account in the preparation of
      these estimates.
 
 While the
oil and gas industry may be subject to regulatory changes from time to time that
could affect an industry participant’s ability to recover its oil and gas
reserves, we are not aware of any such governmental actions which would restrict
the recovery of the December 31, 2009,
 16
 DeGolyer
and MacNaughton
 estimated
oil and gas volumes. The reserves estimated in this report can be produced under
current regulatory guidelines.
 
 DeGolyer
and MacNaughton is an independent petroleum engineering consulting firm that has
been providing petroleum consulting services throughout the world for over 70
years. DeGolyer and MacNaughton does not have any financial interest, including
stock ownership, in
Linn. Our fees were not contingent on the results of our evaluation. This
report has been prepared at the request of Linn and should not be used for
purposes other than those for which it is intended. DeGolyer and MacNaughton has
used all procedures, data, and methods that it considers necessary to prepare
this report.
 
 All gas
quantities in this report are expressed at a temperature base of 60 °F and at
the legal pressure base of the state or area in which the reserves are
located.
  Submitted,
  
 /s/
DeGOLYER and
MacNAUGHTON
 DeGOLYER
and MacNAUGHTON
 Texas
Registered Engineering Firm F-716
  SIGNED:
February 3, 2010
  /s/
Paul J. Szatkowski,
P.E.
 Paul J.
Szatkowski, P.E.
 Senior
Vice President
 DeGolyer
and MacNaughton
  DeGolyer
and MacNaughton
 CERTIFICATE of
QUALIFICATION
 
 I, Paul
J. Szatkowski, Petroleum Engineer with DeGolyer and MacNaughton,
5001 Spring Valley Road, Suite 800 East, Dallas, Texas 75244, U.S.A.,
hereby certify:
 
 1.
              That
      I am a Senior Vice President with DeGolyer and MacNaughton, which company
      did prepare the report entitled “Appraisal Report as of December 31,
      2009 on Certain Properties owned by Linn Energy LLC SEC Case” dated
      February 3, 2010, and that I, as Senior Vice President, was responsible
      for the preparation of this report.
 
 2.
              That
      I attended Texas A&M University, and that I graduated with a Bachelor
      of Science degree in Petroleum Engineering in the year 1974; that I am a
      Registered Professional Engineer in the State of Texas; that I am a member
      of the International Society of Petroleum Engineers; and that I have in
      excess of thirty-five (35) years of experience in oil and gas reservoir
      studies and evaluations.
 
 3.
              That
      DeGolyer and MacNaughton or its officers have no direct or indirect
      interest, nor do they expect to receive any direct or indirect interest in
      any properties or securities of Linn or affiliate
  thereof.
 
 SIGNED:
February 3, 2010
  
  /s/ Paul J. Szatkowski,
P.E.
 Paul J.
Szatkowski, P.E.
 Senior
Vice President
 DeGolyer
and MacNaughton